Alstom Technology Limited

Alstom (switzerland) Ltd

General Electric Company

Ansaldo Energia Switzerland Ag

Ge Vernova Infrastructure Technology LLC

Alston (switzerland) Ltd

Juergen Gerhard Hoffmann

Stefan Rofka

Rolf Dittmann

Ren&eacute; Waelchli

Adnan Eroglu

Alston Ilford Scipio

Michael John Hughes

Sasha Savic

Carlos Jimenez Haertel

Joerg Oesterheld

Thomas Kramer

Armin Busekros

Maruthi Manohar Jupudi

Jost Braun

Charles Matz

Floris Van Straaten

Wolfgang Lang

Rajani Kumar Akula

Mallareddy Soudary

René Waelchli

Michele Pesce

Jochem Fischer

Combustors and methods of operation are provided. The combustor includes a combustion liner that defines a combustion chamber and that extends along an axial centerline from a forward end to an aft end. The combustor further includes a center fuel nozzle that extends along the axial centerline at least partially within the combustion chamber. The combustor further includes a plurality of outer fuel nozzles that surround the center fuel nozzle. The plurality of outer fuel nozzles terminates at the forward end. A venturi injector is positioned in the combustor within the combustion chamber downstream of the center fuel nozzle. The combustor further includes an injector that is coupled to the combustion liner and downstream of the venturi injector.

Flex fuel combustor

A method for inhibiting particulate ingress in a combustion system includes acquiring particulate ingress data, determining a probable particulate ingress location on an air inlet of the combustion system in dependence upon the particulate ingress data, and deploying a filter screen at the determined probable particulate ingress location to inhibit particulate ingress at the determined probable particulate ingress location.

System and method for inhibiting particulate and foreign object ingress in combustion systems

A method for repairing a blade connection of a generator rotor is disclosed. The generator rotor includes an internally threaded hole formed in the generator rotor and an externally threaded blade root. The method includes the steps of removing the blade from the generator rotor, removing material of a first section of the root extending from an end of the root closest to the airfoil, and screwing the blade back into the threaded hole. Additionally, a reworked blade and a reworked blade generator rotor connection is disclosed.

Method for repairing a generator rotor blade connection

The present disclosure refers to a method for operating a gas turbine with sequential combustors having a first-burner, a first combustion chamber, and a second combustor arranged sequentially in a fluid flow connection. To minimize emissions and combustion stability problems during transient changes when the fuel flow to a second combustor is initiated the method includes the steps of increasing the second fuel flow to a minimum flow, and reducing the first fuel flow to the first-burner of the same sequential combustor and/or the fuel flow to at least one other sequential combustor of the sequential combustor arrangement in order keep the total fuel mass flow to the gas turbine substantially constant. Besides the method a gas turbine with a fuel distribution system configured to carry out such a method is disclosed.

Gas turbine with sequential combustion arrangement

An intake manifold is provided for inducting combustion air for a compressor of a gas turbine. The intake manifold includes a plurality of walls that delimit against the environment. Devices are provided for controllable change of the mechanical rigidity of the walls to reduce noise which is generated or is emitted in an air intake region during operation of the gas turbine. A gas turbine is also provided and includes an air intake to which air to be compressed is fed via an intake manifold. The intake manifold having a plurality of walls that delimit against the environment. Devices are provided to controllably change a mechanical rigidity of the walls to reduce noise which is generated or emitted in an air intake region during operation of the gas turbine.

Gas turbine air intake manifold controllably changing a mechnical rigidity of the walls of said intake manifold

A method and gas turbine are provided for the reliable purging of an exhaust gas recirculation line of the gas turbine with exhaust gas recirculation without the use of additional blow-off fans. A blow-off flow of the compressor is used for the purging of the exhaust gas recirculation line. The gas turbine can include at least one purging line which connects a compressor blow-off point to the exhaust gas recirculation line.

Flushing the exhaust gas recirculation lines of a gas turbine

A method for the start of a power plant installation which includes a gas turbine, a generator coupled to the gas turbine, and a frequency converter to feed current into an electrical grid. In accordance with the method, during the start of the gas turbine, the generator is connected to the electrical grid via the frequency converter before the operating rotational speed of the gas turbine is reached, wherein the frequency converter is controlled such that it generates an output current with the grid frequency. A power plant installation can execute the above method.

Gas turbine start with frequency convertor

A silencer in a flow duct () comprises at least one plate-shaped element () which extends essentially parallel to the throughflow direction () of the flow duct. Integrated in the plate-shaped element (), preferably in the downstream region, are means () for feeding and for spraying a liquid () into the throughflow of the flow duct. The spraying means are preferably arranged in such a way that the liquid () is sprayed at an angle of at least 30&#xb0; to the throughflow (). The silencer according to the invention is used, for example, in the intake duct of a gas turboset.

Device for sound attenuation in a flow duct

A liquid atomizing arrangement comprises: a line system, at least one pressure atomizer nozzle, at least one line for the liquid to be atomized, and at least one first actuator for setting the atomizing supply pressure and/or the liquid mass flow through the atomizing arrangement. method of operating the liquid atomizing arrangement comprises the steps of measuring the mass flow flowing through the liquid atomizing arrangement, of measuring the atomizing supply pressure upstream of the pressure atomizer nozzle, and of acting upon the first actuator as a function of at least one of these measured values.

Method of operating an atomizing arrangement

The injection of finely atomized liquid-droplets into the intake air flow of a compressor is used, for example, to improve the output of a gas turbine. If the atomization is effected via pressure atomizer nozzles, it is advantageous, when the injection device is operated with a portion of the design mass flow, to admit liquid to only some of the atomizer nozzles of the injection device. The atomizer nozzles may be arranged on nozzle tubes, liquid being jointly admitted to all the atomizer nozzles arranged on a respective nozzle tube, operated in such a way that the same mass flow is injected on each side of a symmetry line. To this end, nozzle tubes may be combined to form groups, to which liquid is jointly admitted, and the tubes of a group may be arranged in mirror image to one another relative to the symmetry line.

Method of controlling the injection of liquid into an inflow duct of a prime mover or driven machine

A gas turbine set, with a cooling air system through which at least one cooling air mass flow flows from a compressor to thermally highly loaded components of the gas turbine set. Pressure increasing ejectors are arranged in a cooling air duct of the cooling air system for increasing the pressure of flowing cooling air. The ejectors are operable with a working fluid. The working fluid mass flow is less than twenty percent of a driven cooling air mass flow.

Gas turbine set

A gas turbine plant includes at least one compressor compressing intake air, at least one component for heat supply heating the intake air compressed by the compressor, at least one gas turbine using as a working medium the hot air from the component for heat supply, and at least one generator coupled to the gas turbine. A cooling device is provided which permits the cooling of at least a portion of the intake air and/or a portion of partially compressed intake air within the at least one compressor.

Gas turbine plant and process for limiting a critical process value

For supporting the cooling of an air-cooled gas turbine set, it is proposed to arrange, in the cooling air ducts of the cooling system, means for increasing the pressure of the flowing cooling air. In an embodiment, the cooling system ( ) is supplied with high pressure compressor air from the end stages of the compressor ( ) of a gas turbine set ( ). This cooling system branches into a first branch ( ), by means of which the combustor ( ) and the first stages, particularly the first guide blade row of the turbine ( ), are cooled. A second branch ( ) conducts cooling air to the further turbine stages. An ejector ( ) is provided for increasing, as needed, the pressure drop available by means of the first branch ( ) of the cooling system. Its ejector nozzle ( ) is supplied with live steam ( ) taken from a waste heat steam generator ( ), the live steam supply being adjustable by means of an adjusting member ( ). The invention is found to be generally suitable for flexibly configuring the cooling air initial pressure and thereby the cooling air mass flow.

A gas turbo set ( ) is equipped with at least a cooling air system ( ). Throttle points ( ) are arranged as throttling points in the cooling air flowpath, for the purpose of defining the cooling air mass flow. Said manifolds are bypassed by bypass lines ( ). Means ( ) are arranged in said bypass lines for adjusting the bypass mass flow. Thus, the cooling air mass flow can be varied without acting on the main cooling air flow as such.

Gas turbo-group with cooling air system

The invention gives a process for the control of the amount of cooling air of a gas turbine set ( ). Suitable means ( ) are provided in the cooling system ( ) to enable the amount of cooling air to be varied. The control of this means takes place in dependence on an operating parameter (X). This is determined in a computer unit ( ) by suitable combination of measured machine data (p , p ).

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Baden, Switzerland

Juergen Gerhard Hoffmann