A processing facility is provided. The processing facility includes an asphaltenes and metals (AM) removal system configured to process a feed stream to produce a power generation stream, a hydroprocessing feed stream, and an asphaltenes stream. A power generation system is fed by the power generation feed stream. A hydroprocessing system is configured to process the hydroprocessing feed stream to form a gas stream and a liquid stream. A hydrogen production system is configured to produce hydrogen, carbon monoxide and carbon dioxide from the gas feed stream. A carbon dioxide conversion system is configured to produce synthetic hydrocarbons from the carbon dioxide, and a cracking system is configured to process the liquid feed stream.

Provided is a fuel supply system including a main ammonia line through which liquid ammonia flows; a vaporizer connected to an end of the main ammonia line and configured to heat and vaporize the liquid ammonia via heat exchange between a heating medium and the liquid ammonia; a gaseous ammonia line connected to the vaporizer, the gaseous ammonia line configured to guide a gaseous ammonia, which is ammonia vaporized by the vaporizer, as fuel to a combustor of a gas turbine; a liquid ammonia line configured to guide liquid ammonia which has not undergone heat exchange with the heating medium at the vaporizer as fuel to the combustor; and a switching device configured to switch an ammonia supply state between a first state in which the gaseous ammonia is guided from the gaseous ammonia line to the combustor and a second state in which the liquid ammonia is guided from the liquid ammonia line to the combustor.

In a method for thermal processing of catalytically active waste plastics mixture, the mixture is subjected in a receiving tank to a cracking temperature to undergo a cracking reaction. The mixture is transferred to a mixer pump to produce a reaction mixture which is directed into an outgassing chamber of an intermediate tank to produce an outgassed fraction and a non-outgassed liquid fraction. The outgassed fraction to produce fuel is cooled down, and a first portion of the non-outgassed liquid fraction is returned and subjected again to the cracking temperature in the receiving tank. A second portion of the non-outgassed liquid fraction is conducted in a bypass to the outgassing chamber of the intermediate tank for outgassing while fresh mixture is added. Residual matter settling in the intermediate tank is periodically removed.

An integrated chemical looping combustion (CLC) electrical power generation system and method for diesel fuel combining four primary units including: gasification of diesel to ensure complete conversion of fuel, chemical looping combustion with supported nickel-based oxygen carrier on alumina, gas turbine-based power generation and steam turbine-based power generation is described. An external combustion and a heat recovery steam generator (HRSG) are employed to maximize the efficiency of a gas turbine generator and steam turbine generator. The integrated CLC system provides a clean and efficient diesel fueled power generation plant with high CO.sub.2 recovery.

A system includes a controller communicatively coupled to a compressor. The controller is configured to sense an exhaust temperature of a gas turbine system fluidly coupled to the compressor and derive a setpoint based on the sensed exhaust temperature. The controller is also configured to actuate an inlet bleed heat valve based on the derived setpoint and an ambient temperature. The inlet bleed heat valve directs a compressor fluid from the compressor into a fluid intake system fluidly coupled to the compressor upstream of the compressor and configured to intake a fluid.

The present disclosure relates to systems and methods that provide power generation using predominantly CO.sub.2 as a working fluid. In particular, the present disclosure provides for particular configurations for startup of a power generation system whereby the combustor may be ignited before the turbine is functioning at a sufficiently high speed to drive the compressor on a common shaft to conditions whereby a recycle CO.sub.2 stream may be provided to the combustor at a sufficient flow volume and flow pressure. In some embodiments, a bypass line may be utilized to provide additional oxidant in place of the recycle CO.sub.2 stream.

A power plant comprises a steam system, a first electrolyzer, a heat storage system, and a heat exchanger configured to exchange thermal energy between the steam system, the first electrolyzer and the heat storage system. A method of operating an electrolyzer in a combined cycle power plant comprises operating a steam system to convert water to steam, operating an electrolyzer in a standby mode, the electrolyzer configured to convert water and electricity to hydrogen and oxygen when the electrolyzer is in an operating mode, circulating water from the steam system through a heat exchanger, circulating a first heat transfer medium between the electrolyzer and the heat exchanger, and circulating a second heat transfer medium between the heat exchanger and a thermal storage container.

An apparatus includes an electric generator that includes a fluid inlet configured to receive hydrogen at a first pressure, a turbine wheel configured to expand the hydrogen and rotate in response to expansion of the hydrogen flowing into an inlet of the turbine wheel and out of the outlet of the turbine wheel, a rotor coupled to the turbine wheel and configured to rotate with the turbine wheel, a stationary stator, the electric generator to generate an alternating current upon rotation of the rotor within the stator, and a fluid outlet configured to output hydrogen at a second pressure less than the first pressure. The apparatus includes a power electronics system electrically connected to an electrical output of the electric generator and to receive alternating current from the electric generator. The power electronics can condition the generated electrical current to supply power to various types of loads.

Electrical power systems, including generating capacity of a gas turbine are provided, where additional electrical power is generated utilizing a separate engine and auxiliary air injection system. The gas turbine and separate engine can operate on different fuel types.

By using a combustion flue gas (18) from a power turbine (16), a high-pressure secondary compressed air (12C) is subjected to heat exchange in a first heat exchange unit (19A) of an exhaust heat recovery device (19), and by using resultant heat-exchanged flue gas (18A), a low-pressure primary compressed air (12A) is subjected to heat recovery in a second heat exchange unit (19B) of a saturator (31). Then, a primary compressed air (12B) that has been subjected to heat recovery in the second heat exchange unit (19B) is introduced into a secondary air compressor (22) to increase the pressure of the air, and then the high-pressure air is subjected to heat recovery in the first heat exchange unit (19A), producing a secondary compressed air (12D). The secondary compressed air (12D) is introduced into a combustor (14) and combusted using fuel.