Alstom Technology Limited

Ansaldo Energia Switzerland Ag

General Electric Company

Ansaldo Energia IP UK Limited

Jürgen Gerhard Hoffmann

Thomas Meindl

Giacomo Bolis

Gustav Hagström

Thorsten Wasmuth

Stefan Rofka

Anton Nemet

Hongtao Li

Hans Wettstein

Richard Carroni

Jaan Hellat

Eribert Benz

Carlos Enrique Diaz

Christoph Bernhard Ruchti

Wilhelm Reiter

Frank Sander

Francois Droux

Holger Gerhard Nagel

Klaus-Dieter Liedtke

Jost Braun

Herbert Fuchs

Alexander Zagorskiy

Hans Peter Knöpfel

René Wälchli

Bernhard Wippel

Martin Nicklas

Hartmut Hähnle

Wolfgang Lang

Uwe Möller

Michele Pesce

Johann Josef Daxer

Andreas Ullrich

Tom Alexander Odin McKay

Nikolaus Herbert Kurz

Tobias Spitzmüller

A gas turbine with a sequential combustor arrangement as disclosed includes a first combustor with a first burner for admitting a first fuel into a combustor inlet gas during operation and a first combustion chamber for burning the first fuel, a dilution gas admixer for admixing a dilution gas to the first combustor combustion products leaving the first combustion chamber, a second burner for admixing a second fuel and a second combustion chamber. To assure a temperature profile after the dilution gas admixer and to increase the gas turbine's power and efficiency a vane and/or blade of the turbine has a closed loop cooling. The outlet of the closed loop cooling is connected to the dilution gas admixer for admixing the heated cooling gas leaving the vane and/or blade into the first combustor combustion products.

Sequential combustion arrangement with cooling gas for dilution

A gas turbine and method are disclosed by which the gas turbine can be safely operated at nominal speed with reduced margin to a surge limit of a compressor. The gas turbine, via a directly driven generator which generates alternating current with an operating frequency and which is connected in a frequency-coupled manner to an electricity grid, can deliver electric power to this grid. In the case of an underfrequency event the compressor of the gas turbine is unloaded by controlled, fast closing of the variable compressor guide vanes (VGV) and as a result maintains a sufficient margin to the surge limit of the compressor.

Gas turbine and method for its operation

The disclosure relates to a method for determining a temperature in a pressurized flow path of a gas turbine comprising the steps of sending an acoustic signal from an acoustic signal emitting transducer across a section of the pressurized flow path, detecting the acoustic signal with a receiving transducer, measuring the time needed by the acoustic signal to travel from the acoustic signal emitting transducer to the receiving transducer, calculating the speed of sound, and calculating the temperature as a function of the speed of sound, the heat capacity ratio (&#x25a1;) and a specific gas constant (R) of the gas flowing in the pressurized flow path. Besides the method, a gas turbine with a processor and transducers arranged to carry out such a method is disclosed.

Gas turbine temperature measurement

The invention relates to a method for operating a gas turbine power plant, including a gas turbine, a HRSG following the gas turbine, an exhaust gas blower, and a carbon dioxide separation plant which separates the carbon dioxide contained in the exhaust gases and discharges it to a carbon dioxide outlet, the gas turbine, HRSG, exhaust gas blower, and carbon dioxide separation plant being connected by means of exhaust gas lines. According to the method a trip of the gas turbine power plant includes the steps of: stopping the fuel supply, switching off the exhaust gas blower, and controlling the opening angle of a VIGV at a position bigger or equal to a position required to keep a pressure in the exhaust gas lines between the HRSG and the exhaust gas blower above a minimum required pressure. The invention relates, further relates to a gas turbine power plant configured to carry out such a method.

Operation of gas turbine power plant with carbon dioxide separation

A power station () is provided having a turbine shafting () including a gas turbine () and a generator () which is driven directly by the gas turbine (), produces alternating current at an operating frequency and whose output is connected to an electrical grid () with a predetermined grid frequency. An electronic decoupling apparatus or a variable electronic gearbox () is arranged between the generator () and the electrical grid (), and decouples the operating frequency from the grid frequency.

Power station and method for its operation

An exemplary system method for the operation of a CCPP with flue gas recirculation to reduce NOx emissions and/or to increase the CO2 concentration in the flue gases to facilitate CO2 capture from the flue gases is disclosed. The flue gas recirculation rate (rFRG) is controlled as function of the combustion pressure and/or the hot gas temperature. Operability is enhanced by admixing of oxygen or oxygen enriched air to the gas turbine inlet gases or to the combustion.

Combined cycle power plant with flue gas recirculation

A method is provided for COseparation from a combined-cycle power plant with exhaust-gas recirculation and COseparation. The hot-gas flow is split into a recirculation flow and an exhaust-gas flow before the final turbine stage in the turbine. A first partial flow remains in the turbine and carries out expansion work in the conventional form, before its waste heat is dissipated, for example in a waste-heat boiler, and the gases are recirculated into the inlet flow of the gas turbine. A second partial flow is diverted before the final turbine stage, and emits its waste heat in an HRSG/heat exchanger, before COis separated from the exhaust-gas flow at an increased pressure level.

Gas turbine with flow separation and recirculation

A power plant includes a first gas turbine engine, a second gas turbine engine, a flue gas duct, a COcapture system for treating flue gases from the second gas turbine engine and an exhaust system. It additionally includes at least one among a direct connection between the first gas turbine engine and the exhaust system, and a damper for on-line regulating the flue gases flow through it, a direct connection between the first gas turbine engine and the COcapture system, and a damper for regulating the flue gases flow through it, a supply of fresh oxygen containing fluid for the second gas turbine engine.

Power plant and method for retrofit

An exemplary method is disclosed for operating a gas turbine power plant with exhaust gas recirculation, in which the exhaust gas recirculation is, for example, disengaged during starting and shutting down of the gas turbine, and in which the engaging or disengaging of the exhaust gas recirculation can be carried out in dependence upon an operating state of the gas turbine. An exemplary gas turbine power plant with exhaust gas recirculation is also disclosed which can include a control element, the closing speed of which is such that the control element can be closed within a time which is less than a time for exhaust gases to flow from the turbine through an HRSG.

Method for operating a gas turbine power plant with exhaust gas recirculation

COcompression is a main step in carbon capture and storage, which is essential to control global warming. COcompressors are powered by electric motors, which increase operational flexibility but require much energy leading to additional expenses, power and efficiency losses. A method is provided for optimized operation of a plant including a power generation unit with a COcapture system and compressor with minimum losses during normal operation, allowing flexible part load. The method allows steam from the power unit to drive a steam turbine, which drives the COcompressor via an engaged overrunning clutch if a sufficient amount of steam is available from the power unit, and to drive it by the generator, which is used as motor when insufficient steam is available from the power unit. When no or insufficient steam is available the clutch is disengaged and the steam turbine may be at standstill or idling.

[object Object]

A method is provided for operating a gas turbine in a power station in which limits of the operating concept, which provide limits for optimization of the power station operation in respect of efficiency, service life consumption, emissions and power provision to the grid system, are adapted during operation. In particular, temperature limits and compressor inlet guide vane position limits are varied as a function of the optimization aims. A gas turbine power station is also provided for carrying out the method.

Method for controlling a gas turbine in a power station, and a power station for carrying out the method

A method is provided for operating a power station () with turbine shafting () including a gas turbine () and a generator () that is driven directly by the gas turbine () and that generates alternating current with an operating frequency. The output of the generator is connected to an electrical grid () with a given grid frequency. An electronic decoupling apparatus or variable electronic gearbox () is arranged between the generator () and the grid (). The decoupling apparatus decouples the operating frequency from the grid frequency. In the event of a temporary over-frequency or under-frequency event in the electrical grid (), the mechanical rotational speed of the gas turbine () is decreased more than the grid frequency during an under-frequency event of the electrical grid () and is increased more than the grid frequency during an over-frequency event of the electrical grid ().

Method for operating a power plant

A method is provided for operating a power station (), with turbine shafting (), that includes a gas turbine () and a generator () driven directly by the gas turbine () and that generates alternating current with an operating frequency, the output of the generator is connected with an electrical grid () with given grid frequency. An electronic decoupling apparatus or variable electronic gearbox () is arranged between the generator () and the grid (), the decoupling apparatus decouples the operating frequency from the grid frequency. Increased service life of the station and reduced emissions are achieved in that, when there are longer-lasting changes in the grid frequency, the mechanical or aerodynamic rotational speed of the gas turbine () is kept constant and the output of the gas turbine () is adjusted without a delay.

A combined-cycle power plant () has at least one power train () including a steam turbine () and a second generator () directly driven by the steam turbine () and generating alternating current, the output of which generator is connected to a power grid () having a given grid frequency (F), and at least one power train () of a gas turbine () and a first generator () driven directly by the gas turbine () and generating alternating current with an operating frequency, the output of which generator is connected to a power grid () having a predetermined grid frequency. An electronic decoupling device or a variable electronic gear unit () decouples the operating frequency from the grid frequency and is arranged between the first generator () and the power grid (). Such a plant allows both flexible steady-state operation with high overall efficiency as well as flexible transient operation.

Power station with grid frequency linked turbine and method for operating

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

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Untersiggenthal, Switzerland

Jürgen Gerhard Hoffmann