a hydrogen refueling system for refueling a vehicle with hydrogen. The system comprises a hydrogen supply, a hydrogen center enclosure comprising a cooling system. The cooling system is arranged for cooling the hydrogen delivered to the vehicle. The system further comprises a dispenser arranged for supplying the hydrogen to the vessel of the vehicle. A supply pipe is arranged for guiding the hydrogen from the center enclosure to the dispenser. The system further comprises a forward path arranged for guiding a supply pipe cooling media from the hydrogen center enclosure towards the dispenser, and a return path arranged for guiding at least a fraction of the supply pipe cooling media back to the hydrogen center enclosure, where at least one of the forward and return paths are thermally connected with the cooling system.

An energy storage system is provided. The system comprises an energy storage device comprising: a pressure vessel configured to store pressurised fluid; and one or more resilient elements, wherein the resilient elements comprise a plurality of filaments of resilient material braided to form the resilient elements, wherein the resilient elements are arranged within or about the pressure vessel, and wherein the energy storage device is configured such that storing pressurised fluid within the pressure vessel acts to tension or compress the resilient elements.

Systems and methods for dockside regasification of liquefied natural gas (LNG) are described herein. The methods include providing LNG from a LNG carrier to a regasification vessel. The LNG may be regasified on the regasification vessel. The regasified natural gas may be discharged with a high pressure arm to a dock and delivered onshore. The regasification vessel may be moored to the dock. The LNG carrier may be moored to the regasification vessel or the dock.

A method of operating a hydrostatically compensated compressed air energy storage system in a first charging mode including conveying the compressed air at a nearly constant first operating pressure which displaces a corresponding volume of compensation liquid from the layer of compensation liquid out of the accumulator, and a second charging mode including conveying additional compressed air into the accumulator while compensation liquid is not displaced from within the accumulator so that the pressure of the layer of compressed air increases to a second operating pressure that is greater than the first operating pressure.

The present invention relates to a gas storage apparatus and method, and more specifically to liquid air energy storage and its use to facilitate both Demand Side Reduction (DSR) and the use of reduced-cost electricity by industrial compressed-air users. A related electricity generating apparatus and method is also disclosed. The apparatus and method use a first sensible heat coolth store and second latent heat coolth store to first reduce the gas in temperature and then to change it into a liquid phase. Coolth top up devices are also disclosed.

A method of temporarily storing thermal energy via a thermal storage subsystem in a compressed air energy storage system comprising an accumulator disposed at least 300 m underground and having an interior configured to contain compressed air at an accumulator pressure that is at least 20 bar and a gas compressor/expander subsystem in communication with the accumulator via an air flow path for conveying compressed air to the accumulator when in a charging mode and from the accumulator when in a discharging mode.

A power supply 100 is described. The power supply 100 has a first electrical outlet 110 and comprises: optionally a set of hydrogen storage devices 200, including a first hydrogen storage device 200A, a set of heaters 300, including a first heater 300A, a first releasable fluid inlet coupling 410 and/or a first releasable fluid outlet coupling 510; wherein the first hydrogen storage device 200A comprises: a pressure vessel 230A, having a first fluid inlet 210A and a first fluid outlet 220A, comprising therein a thermally conducting network 240A optionally thermally coupled to the first heater 300A, wherein the pressure vessel 230A is arranged to receive therein a hydrogen storage material 250A in thermal contact, at least in part, with the thermally conducting network 240A, wherein the first fluid inlet 210A and/or the first fluid outlet 220A are in fluid communication with the first releasable fluid inlet coupling 410 and/or the first releasable fluid outlet coupling 510, respectively; and preferably, wherein the thermally conducting network 240A has lattice geometry and/or a fractal geometry in two and/or three dimensions.

The present invention is a pressure tank comprising a tubular part and two bottoms (5) with the bottoms (5) positioned at the ends of the tubular part. The tubular part comprises a cylindrical wall (1) and a ply of circumferential reinforcing elements (2) wound around cylindrical wall (1). The elastic modulus of the material of cylindrical wall (1) is less than the elastic modulus of the material of the first ply of circumferential reinforcing elements (2). The invention also relates to an energy storage and recovery system comprising a compressor, an expansion device, a heat storage and a compressed air tank according to the aforementioned characteristics.

A method of storing hydrogen gas in a subsurface formation may include compressing hydrogen gas by utilizing a compressor. This may create pressurized hydrogen gas that may be introduced into a subsurface formation through a wellhead to store as reserved hydrogen gas. The reserved hydrogen gas may be stored and maintained in the subsurface formations for a period. Another method in accordance with one or more embodiments of the present disclosure relates to recovering previously stored hydrogen gas from a subsurface storage for energy production. The method may include extracting reserved hydrogen gas from a subsurface formation. The extracted hydrogen gas may be purified by using at least a dehydrator, a pressure swing adsorption unit (PSA) and at least a temperature swing adsorption unit (TSA). The purified hydrogen gas may then be pressurized and used as a fuel for combustion in a turbine-generator unit.

The present invention provides a complex power generation facility including a first transfer unit that transfers liquefied natural gas; a first heat exchange apparatus that causes the liquefied natural gas supplied from the first transfer unit to exchange heat with seawater, vaporizes the liquefied natural gas into natural gas, heats the seawater into hot water, and discharges the hot water; a second heat exchange apparatus that selectively receives the hot water discharged from the first heat exchange apparatus and caused the natural gas passing through the first heat exchange apparatus to exchange heat with seawater and hot water; and a power generation unit that generates power as the natural gas supplied from the second heat exchange apparatus passes therethrough.