Embodiments are generally provided of a gas turbine engine including a rotor assembly comprising a shaft extended along a longitudinal direction, in which a compressor rotor and a turbine rotor are each coupled to the shaft; a casing surrounding the rotor assembly, in which the casing defines a first opening radially outward of the compressor rotor, the turbine rotor, or both, and a second opening radially outward of the compressor rotor, the turbine rotor, or both; a first manifold assembly coupled to the casing at the first opening; a second manifold assembly coupled to the casing at the second opening, in which the first manifold, the casing, and the second manifold together define a thermal circuit in thermal communication with the rotor assembly; and a fluid flow device in fluid communication with the first manifold assembly, in which the fluid flow device provides a flow of fluid to the first manifold assembly and through the thermal circuit, and further wherein the flow of fluid egresses the thermal circuit at the second manifold assembly.

Systems, apparatus and methods for efficiently operating a chiller plant while minimizing or eliminating the occurrence of centrifugal compressor surge. Taking into account chiller design specifications and current operating conditions, a compressor lift point at which surge is predicted to occur is established. Minima and maxima for various chiller setpoints that avoid or eliminate the occurrence of compressor surge are imposed on setpoints provided by a conventional optimizing chiller controller. The chiller system is operated in accordance with the resultant anti-surge setpoints. Energy savings is realized by modulating coolant tower flow to enable the compressor to operate at near-surge conditions while preventing the onset of actual surge.

The present disclosure is directed to turbine engines and systems for active stability control of rotating compression systems utilizing an electric machine operatively coupled thereto. In one exemplary aspect, an electric machine operatively coupled with a compression system, e.g., via a shaft system, is controlled to provide shaft damping for instability fluctuations of the pressurized fluid stream within the compression system. Based on control data indicative of a system state of the compression system, a control parameter of the electric machine is adjusted to control or change an output of the shaft system. Adjusting the shaft system output by adjusting one or more control parameters of the electric machine allows the compression system to dampen instability fluctuations of the fluid stream within the compression system. A method for active stability control of a compression system operatively coupled with an electric machine via a shaft system is also provided.

A compressor system including: a first compressor having a compressor suction side and a compressor delivery side; an anti-surge line having an inlet and an outlet; an anti-surge valve arranged along the anti-surge line and controlled for recirculating a gas flow from the compressor delivery side back to the compressor suction side; a gas temperature manipulation arrangement, functionally connected to the inlet of the anti-surge line, configured to reduce or prevent liquid phase in the anti-surge line when the anti-surge valve is open.

A method for preventing damage to a multiphase pump includes measuring a differential pressure of a fluid across the pump and an axial position of a rotor of the pump over a time period, calculating a pressure fluctuation by measuring a difference between a maximum and a minimum value of the measured differential pressure over the time period, calculating a dynamic axial position by measuring a difference between a maximum and a minimum value of the measured axial position of the rotor over the time period, comparing the calculated pressure fluctuation with an expected pressure fluctuation value, comparing the calculated dynamic axial position with an expected dynamic axial position value, and selecting an operating condition of the pump based on the comparison of the calculated pressure fluctuation with the expected pressure fluctuation value and of the calculated dynamic axial position with the expected dynamic axial position value.

A method of surge protection for a dynamic compressor that has a corresponding compressor map. A control system continually calculates an equivalent polytropic head parameter in order to define a surge limit line. The system then calculates a control parameter and determines the distance the control parameter to the surge limit line wherein the control parameter is dynamic to changes in gas compressibility and invariant to changes in suction conditions and gas compressibility. As a result of the distance of the control parameter to the surge limit line, the surge valve of a dynamic compressor is actuated to prevent surge.

A compressor system includes; a compression section that sucks and compresses gas; a rotor that includes the compression section; a gas bearing that supports the rotor; a dynamic-pressure generating gas supply system that supplies, to a gas supply port for dynamic pressure of the gas bearing, bleed gas from the gas pressurized by the compression section; and an external gas supply system for static pressure that supplies, to a gas supply port for static pressure of the gas bearing, external gas from outside of the compression section. The dynamic-pressure generating gas supply system and the external gas supply system for static pressure respectively include paths that are independent of each other to the gas bearing. The gas supply port for dynamic pressure and the gas supply port for static pressure are independent of each other.

A technique is provided that can further reduce power at the time of unload operation control in a gas compressor that generates a compressed gas at a set pressure by constant-speed control. The gas compressor includes a compressor main unit, a drive source, an intake throttle valve, a gas release valve, rotation speed converting means, a pressure detecting device that detects a discharge pressure, and a controller that, the relationship between an upper-limit pressure H and a lower-limit pressure L being H>L, carries out opening the intake throttle valve and closing the gas release valve and operating the drive source at a full-load rotation speed until the discharge pressure reaches the upper-limit pressure H. The controller carries out at least one of closing the intake throttle valve and opening the gas release valve to reduce the discharge pressure to within a predetermined range when the discharge pressure reaches the upper-limit pressure H. The controller carries out switching to load operation when the discharge pressure drops to the lower-limit pressure L. In the gas compressor, the controller outputs a command of a lower rotation speed than the full-load rotation speed to the rotation speed converting means when the discharge pressure rises and reaches the upper-limit pressure H. The controller outputs a command of the full-load rotation speed to the rotation speed converting means when the discharge pressure drops and reaches the lower-limit pressure L.

Controller, control actuator and bleed valve including a first chamber for the circulation of a discharge air stream when the valve is open and preventing it when the valve is closed, an inner housing, in which a mobile blocking unit is moved between a position for opening and a position for closing the valve, this unit delimiting, in the inner housing, two chambers, the second chamber including a mechanism for returning the blocking unit to the open position, and the third chamber, being used to be in fluidic connection with the control actuator in order to actuate the blocking unit against the return mechanism, the three chambers being isolated in a sealed manner from one another by way of the blocking unit. The device includes a regulation valve.

Disclosed herein is a method for controlling a surge margin of a gas turbine and an extraction device for a gas turbine. The method for controlling the surge margin of the gas turbine and the extraction device for the gas turbine may support stable operation of a compressor unit in the gas turbine, thereby improving the efficiency of the gas turbine and minimizing vibration and noise of the gas turbine.