General Electric Company

Philip Lynn Andrew

John David Stampfli

Joseph Anthony Cotroneo

John Edward Ford

Timothy Andrew Melsert

Aleksandar Prole

Chung-Hei Yeung

Gary Michael Itzel

Paul Stephen DiMascio

James Michael Fogarty

Matthew Ryan Ferslew

Paul Thomas Marks

Steven Mark Schirle

Frederick J Rink, Jr

Ramani Mani

Harold Edward Miller

Daniel Robert Dwyer

Hyoun-woo Shin

Ronald Richard Wesorick

Christopher Edward Miller

Pierluigi Nava

Joseph Chapman

James Michael Hill

Marco Mazzoni

A flow diverter for an air separator of a gas turbine includes a cylindrical body configured to fit within a cooling hole of the air separator. One or more air flow vents are defined through and around a partial circumference of the cylindrical body. A bottom panel closes the cylindrical body at one end. A mounting flange surrounds the cylindrical body at an open end and extends radially outward from the cylindrical body. When the flow diverter is installed, air flows through the open end in a radial direction and exits through the air flow vents in an axial direction. The cylindrical body may include a collapsible region that collapses to engage the air separator and prevent the flow diverter from being dislodged. The air separator may additionally or alternately include supplemental cooling holes in a recessed area proximate to its mounting flange.

Flow-diverting systems for gas turbine air separator

The present application provides a compressor for a gas turbine. The compressor may include a number of rotor wheels positioned about a compressor aft section having a low alloy material, a number of inlet guide vanes positioned about a compressor inlet section, and a wet compression system positioned about the compressor inlet section.

Gas turbine compressor and method of operation

Systems and methods for controlling a gas turbine are disclosed. The gas turbine can include a compressor oversized in airflow capacity and one or variable blade rows to control the airflow into the compressor. The position of the variable blade rows can be controlled according to a nominal variable blade row schedule that is defined to throttle down the variable blade rows to provide nominal flow into the compressor. The positions of the variable blade rows can be adjusted from the nominal positions set forth in the variable blade row schedule pursuant to a request to operate the gas turbine system in either a controlled output mode or in a frequency compensation mode.

System and method for hot ambient and grid frequency compensation for a gas turbine

In one embodiment a transition section for a turbine engine is provided that includes one or more components constructed of a ceramic matrix composite. The transition section may fluidly connect a high-pressure turbine and a low-pressure turbine within the gas turbine engine. The transition section may include a transition duct and a variable area turbine nozzle. One or both of the transition duct and the variable area turbine nozzle may be constructed of the ceramic matrix composite.

Ceramic matrix composite turbine engine

A system, in certain embodiments, includes a magnetic actuator configured to adjust a radial clearance between a housing and rotary blades via translational movement along a rotational axis. The system includes a controller configured to engage the magnetic actuator to adjust the radial clearance in response to feedback.

Method and apparatus for clearance control

A bucket for a steam turbine includes an airfoil portion having a radially outer tip, the radially outer tip having a thermal barrier coating applied thereto, and wherein the thermal barrier coating is resurfaced to form at least one ridge along the radially outer tip.

Steam-cooled gas turbine bucker for reduced tip leakage loss

Methods and apparatus for operating a combined-cycle power system are provided. The method includes operating the steam turbine, the combustion turbine, and the steam source at steady state operating conditions. Upon sensing a grid frequency deviation away from the standardized grid frequency value, determining a current thermal energy capacity of the steam source, determining a rate of frequency recovery available using the current thermal energy capacity of the steam source and a predetermined rate of change of the at least one steam turbine control valve, if the determined rate of frequency recovery available is greater than the grid frequency deviation, mitigating the frequency deviation using the current thermal energy capacity, if the determined rate of frequency recovery available is less than the grid frequency deviation then mitigating the frequency deviation using the current thermal energy capacity substantially simultaneously with a power level increase of the combustion turbine.

Methods and apparatus for electric power grid frequency stabilization

A method and apparatus for operating a combined-cycle power system is provided. The system is coupled to an electric power grid. The system includes at least one electric power generator, at least one steam turbine coupled to the generator, at least one combustion turbine coupled to the generator, and at least one steam source that is in flow communication with the steam turbine. The method includes operating the system at a first power output level with the steam turbine and the combustion turbine being synchronized to an operating frequency of the grid, so that the steam turbine, the combustion turbine, and the grid are operating at a frequency substantially similar to a standardized grid frequency value. The method also includes sensing a grid frequency deviation away from the standardized grid frequency value. The method further includes accelerating or decelerating the turbines and facilitating a predetermined rate of grid frequency recovery for a predetermined period of time, such that the predetermined rate of frequency recovery is substantially uniform.

A non-intrusive method of monitoring the integrity of a rotating member comprising mounting at least one sensor in a stationary frame of reference in a casing over the rotating member, measuring the pressure field of the rotating member, comparing the measured pressure field with a corresponding reference pressure field, identifying variations in the measured pressure field, the variations indicative of a fault in the rotating member, and generating an output indicative of an identified fault.

Method and apparatus for non-intrusive monitoring of rotating components

A method is disclosed for monitoring and controlling a compressor including (a) monitoring at least one compressor parameter; (b) storing data indicative of the monitored parameter in a database system; (c) processing the collected data using a stall precursor detection algorithm to determine a stall precursor; (d) comparing the stall precursor with at least one of a corresponding average compressor value, and a corresponding unit specific value to determine the level of compressor operability, and (e) if the stall precursor varies from at least one of the average compressor value and the unit specific value, performing corrective actions to vary the level of compressor operability to prevent a surge condition.

Method and apparatus for detecting and compensating for compressor surge in a gas turbine using remote monitoring and diagnostics

A transfer function between the inlet air-flow consumed by a Gas Turbine engine, and the engine parameters of speed, pressure ratio, and Inlet Guide Vane (IGV) angle is described. An active compressor Operating Limit Line (OLL) management strategy that leverages this improved flow measurement transfer function is also described. The improved flow measurement capability afforded by the transfer function permits a deterioration in flow rate caused by compressor fouling to be detected. Using the deterioration in flow rate as a proxy for compressor fouling, a degraded surge boundary associated with fouling can be predicted, using a transfer function between degradation of air-flow along operating line and degradation of surge line. In combination, the inventive improvements in flow measurement and operating line management afford added compressor surge protection across the operating range, while permitting the attainment of elevated pressure ratios associated with high thermodynamic efficiency and output.

Method of air-flow measurement and active operating limit line management for compressor surge avoidance

In a dynamoelectric machine, stacked turns are provided with registering openings for the flow of a cooling medium from a subslot radially within the rotor in a direction radially outwardly to cool the turns. Turbulators are provided in each of the turns to enhance the turbulent flow of the cooling medium which enhances the heat transfer between the heated turn and the cooling medium. The turbulators are formed by a coining operation after the openings are punched through the turn to form an inwardly directed rib effecting turbulent flow in that region and enhanced cooling effects.

Dynamoelectric machines having rotor windings with turbulated cooling passages

A gas turbine operational strategy is provided for the optimization of ISO-Day rated performance. The invention is realized by setting the nominal operating line equal to or slightly below the operating limit line, so that ISO full load performance is maximized. Thus, the first stage turbine nozzle throat area is sized such that, without inlet bleed heat addition, and at Base-Load pressure ratio and firing temperature, the compressor operates within its operational limits on a ISO day. As ambient conditions change, levels of inlet bleed heat and firing temperature are controlled and the inlet guide vane angle is set whereby the nominal operating line is equal to or slightly below the operating limit line.

Method of operation of industrial gas turbine for optimal performance

The surge pressure ratio of a compressor is determined by transiently reducing the inlet flow to the compressor to increase the compressor pressure ratio sufficiently to produce the surge pressure ratio. The reduction in flow of fluid is maintained for a time period insufficient to exceed the exhaust gas temperature limit for the turbine. The area of the first-stage nozzle of the turbine is reduced and the inlet flow to the compressor is reduced to a steady state to achieve pressure ratios, in close proximity to the surge line. By transiently further reducing the inlet flow to the compressor and then increasing the inlet flow back to the steady-state condition, the surge pressure ratio can be obtained without exceeding machine operational limits.

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Simpsonville, SC, United States of America

Philip Lynn Andrew