A system includes a controller including a memory storing instructions and a processor that executes the instructions. The instructions cause the controller to control a steam turbine system coupled to a power generation system to release steam during deceleration of a gas turbine. The instructions cause the controller to receive a first temperature of the gas turbine and a rotational speed of the gas turbine. The instructions cause the controller to calculate an exhaust flow rate of the power generation system based on at least the first input signal and the second input signal. The instructions cause the controller to control the power generation system to isolate a fuel source from the gas turbine at a portion of normal operating speed of the gas turbine sufficient to achieve a predetermined purging volume during coast down of air flow through the power generation system based on the exhaust flow rate.

A system includes a controller including a memory storing instructions to perform operations of a power generation system and a processor that executes the instructions. The instructions cause the controller to control purging fluid flow to an inlet of a gas turbine, an exhaust of the gas turbine, or a combustion section of the gas turbine. The instructions cause the controller to receive a first temperature at the inlet, a rotational speed of the gas turbine, and a purging fluid flow rate. The instructions cause the controller to calculate an exhaust flow rate of the system based on at least the first temperature, the rotational speed, and the purging fluid flow rate. The instructions cause the controller to control the system to isolate a fuel source from the gas turbine at a portion of normal operating speed sufficient to achieve a purging volume during coast down.

According to one aspect of the present disclosure, a drain system, including a sensor in communication with a reservoir and controller, uses algorithmic control of a drain valve to adjust the interval and duration of actuation of the drain valve to regulate a fluid level within the reservoir. In embodiments applying the drain system to a gas compressor system, the disclosed control algorithm enables the controller to prevent the loss of compressed gas through an open path out the drain and further to prevent condensate generated by operation of the compressor system from backing up in the reservoir and reentering the flow of compressed gas. The control algorithm adjusts the interval and period of actuation of the drain valve such that as operating conditions change the drain valve opens more or less frequently for longer or shorter periods in response to varying condensate load.

According to one aspect of the present disclosure, a drain system, including a sensor in communication with a reservoir and controller, uses algorithmic control of a drain valve to adjust the interval and duration of actuation of the drain valve to regulate a fluid level within the reservoir. In embodiments applying the drain system to a gas compressor system, the disclosed control algorithm enables the controller to prevent the loss of compressed gas through an open path out the drain and further to prevent condensate generated by operation of the compressor system from backing up in the reservoir and reentering the flow of compressed gas. The control algorithm adjusts the interval and period of actuation of the drain valve such that as operating conditions change the drain valve opens more or less frequently for longer or shorter periods in response to varying condensate load.

Rankine Cycle power generation facility having a plurality of thermal inputs and at least one heat sink, where the heat sink includes a thermal chimney or a natural convective cooling tower. In a preferred embodiment, the power facility generates electricity and/or fresh water with a zero carbon footprint, such as by using a combination of solar and geothermal heating to drive a Rankine Cycle heat engine. In one embodiment, a thermal stack is mounted in the base of the thermal chimney, the thermal stack for using waste heat from the plurality of thermal inputs to drive a natural convective flow of air in the thermal chimney, the convective flow having sufficient momentum to drive additional power generation in an air turbine mounted in the chimney and to drive an evaporative cycle for concentratively extracting fresh water from geothermal brines.

Rankine Cycle power generation facility having a plurality of thermal inputs and at least one heat sink, where the heat sink includes a thermal chimney or a natural convective cooling tower. In a preferred embodiment, the power facility generates electricity and/or fresh water with a zero carbon footprint, such as by using a combination of solar and geothermal heating to drive a Rankine Cycle heat engine. In one embodiment, a thermal stack is mounted in the base of the thermal chimney, the thermal stack for using waste heat from the plurality of thermal inputs to drive a natural convective flow of air in the thermal chimney, the convective flow having sufficient momentum to drive additional power generation in an air turbine mounted in the chimney and to drive an evaporative cycle for concentratively extracting fresh water from geothermal brines.

The present invention relates to a cryogenic air separation process that provides high pressure oxygen for an oxy-fired combustion of a fuel (e.g., a carbonaceous fuel). The air separation process can be directly integrated into a closed cycle power production process utilizing a working fluid, such as CO.sub.2. Beneficially, the air separation process can eliminate the need for inter-cooling between air compression stages and rather provide for recycling the adiabatic heat of compression into a process step in further methods wherein an additional heat supply is beneficial.

This invention involves thermal energy and head (height) difference of water level to feed the water into the boiler. This device uses very minimal electrical and mechanical energy to feed the water into the boiler as compared to the amount of both electrical and mechanical energy that is currently being used in the technology that is in use.

According to this invention, this device works with the thermal principle and uses a small amount of steam from the same boiler to feed the water back into that boiler. This is how the device saves huge amount of electrical power and reduces the maintenance as it very few valves instead of many high speed moving components that are being used in the existing technology.

A method for energy storage with co-production of peaking power and liquefied natural gas (LNG) which integrates the processes of liquid air energy storage and reduction in pressure of natural gas through expander at the co-located city gate station and includes consumption of excessive power from the grid, mechanical power of the natural gas expander and cold thermal energy of expanded natural gas for charging the storage with a liquid air during off-peak hours and production of peaking (on-demand) power by the expanders of natural gas and highly-pressurized re-gasified air with recovering the cold thermal energy of expanded natural gas and regasified liquid air for liquefying a part of delivered natural gas at the city gate station and energy storage facility.

A combined cycle power plant is provided. The combined cycle power plant includes a gas turbine and a heat recovery steam generator disposed in fluid communication with the gas turbine and including one or more steam heater units. Additionally, the combined cycle power plant includes a recuperator unit integrated with the heat recovery steam generator and configured to use gas turbine exhaust from the gas turbine to preheat compressor discharge air from the compressor and supply the preheated compressor discharge air to the combustor, where a first subset of the one or more steam heater units is disposed in parallel to the recuperator unit, and where a second subset of the one or more steam heater units is disposed in series with the first subset of the one or more steam heater units and the recuperator unit with respect to a direction of flow of gas turbine exhaust.