A hydrogen station operation method capable of adjusting pressure in a reservoir to the pressure suitable for liquid hydrogen replenishment while cutting hydrogen waste is for replenishing liquid hydrogen into the reservoir in a hydrogen station including: a gasification path partially gasifying liquid hydrogen out of the reservoir and returning it; and a gas delivery path delivering gasified hydrogen in the reservoir into a path between a vaporizer and a compressor or the vaporizer, when the remainder of liquid hydrogen in the reservoir becomes a first threshold or less, by reducing the liquid hydrogen amount flowing through the gasification path by a valve therein, reducing the gasification amount of liquid hydrogen in the reservoir, and increasing the hydrogen gas amount delivered through the gas delivery path from the reservoir by a valve therein, pressure in the reservoir is reduced, thereby performing operation where suction pressure of the compressor is reduced.

A dispensing assembly for a pressure dispense package includes a connector having separate and distinct liquid and extraction conduits, and having a pressurization gas conduit. A liner fitment adapter may include a longitudinal bore to receive a probe portion of a connector defining a liquid extraction conduit, and may include a lateral bore to enable removal of gas. Insertion of a connector into a dispensing assembly simultaneously makes fluidic connections between (a) a gas extraction conduit and a dispensing volume; (b) a liquid extraction conduit and the dispensing volume, and (c) a pressurization gas conduit and a space to be pressurized within a pressure dispense vessel.

A tank state estimating method of estimating a state in a tank at a predetermined point in time on a sailing course of an LNG carrier is provided. The LNG carrier carrying LNG stored in the tank as a cargo. The tank state estimating method includes: a first step of acquiring information related to specification of the tank; a second step of acquiring information related to a state in the tank at a start point of a target section on the course; a third step of acquiring information on a predictive value of liquid fluctuation of the LNG in the tank during the section, the predictive value being obtained on a basis of a weather forecasting value during the section and information on the weather forecasting value; and a fourth step of calculating the state in the tank at an end point of the section by thermal transfer calculation based on thermodynamics on a basis of the information acquired in the first to third steps in assuming that a heat input to the tank during the section is used for vaporization of the LNG in the tank.

A hydrogen storage tank for a hydrogen fueled aircraft. The tank has a wall made of layers of aerogel sections around a hard shell layer, sealed within a flexible outer layer, and having the air removed to form a vacuum. The periphery of each layer section abuts other sections of that layer, but only overlies the periphery of the sections of other layers at individual points. The wall is characterized by a thermal conductivity that is lower near its gravitational top than its gravitational bottom. The tank has two exit passageways, one being direct, and the other passing through a vapor shield that extends through the wall between two layers of aerogel. A control system controls the relative flow through the two passages to regulate the boil-off rate of the tank.

Disclosed is a liquefied natural gas storage apparatus. The apparatus includes a heat insulated tank and liquefied natural gas contained in the tank. The tank has heat insulation sufficient to maintain liquefied natural gas therein such that most of the liquefied natural gas stays in liquid. The contained liquefied natural gas has a vapor pressure from about 0.3 bar to about 2 bar. The apparatus further includes a safety valve configured to release a part of liquefied natural gas contained in the tank when a vapor pressure of liquefied natural gas within the tank becomes higher than a cut-off pressure. The cut-off pressure is from about 0.3 bar to about 2 bar.

A modular tank system comprising at least two pressure tanks (1,1) and a mounting frame (2), wherein each of the pressure tanks (1,1) comprises a pressure vessel (3) and a protection frame (4) within which the pressure vessel is arranged, the protection frame (4) is adapted such that multiple pressure tanks (1,1) may be mounted on top of each other and the pressure vessel comprises a vent outlet and a first inlet (5), wherein the vent outlet is arranged in an upper half of the pressure vessel, the first inlet (5) is arranged in a lower half of the pressure vessel and is fluidly connected to a tank process line (6), the tank process line comprises a first fluid connector (12) and a second fluid connector (23) on opposite ends of the tank process line, such that the second fluid connector (23) of a first pressure tank (1) is connectable to the first fluid connector (12) of a second pressure tank (1), when the second pressure tank (1) is mounted on top of the first pressure tank (1); and the mounting frame (2) comprises a base frame (15) upon which the at least two pressure tanks (1) may be mounted, the base frame comprises a frame process line (16); the frame process line (16) comprises at least two fluid connectors (20), each fluid connector (20) connectable to the first fluid connector (12) of a tank process line (6) and arranged such that the frame process line (16) may be fluidly connected to the tank process lines (6) of the at least two pressure tanks when the pressure tanks (1) are mounted upon the base frame (15) side by side.

Disclosed is a liquefied natural gas storage apparatus. The apparatus includes a heat insulated tank and liquefied natural gas contained in the tank. The tank has heat insulation sufficient to maintain liquefied natural gas therein such that most of the liquefied natural gas stays in liquid. The contained liquefied natural gas has a vapor pressure from about 0.3 bar to about 2 bar. The apparatus further includes a safety valve configured to release a part of liquefied natural gas contained in the tank when a vapor pressure of liquefied natural gas within the tank becomes higher than a cut-off pressure. The cut-off pressure is from about 0.3 bar to about 2 bar.

A control conduit for liquid hydrogen offloading is configured to couple a controller of a liquid hydrogen offload system to a liquid hydrogen tanker. The control conduit includes a control line and a gas detector. The control line is configured to transmit a control signal from the controller to the liquid hydrogen tanker. The gas detector is configured to detect hydrogen gas and provide a gas detector signal to the controller. The gas detector is secured to the control line at a predetermined distance from a tanker connection end of the control line.

An insulation arrangement configured to cover a vessel containing a liquified gas is provided. Embodiments include an insulation arrangement including an aerogel composition and a vapor barrier, where the insulation arrangement reduces heat transfer between the ambient environment and the liquified gas. Other embodiments include an insulated clamping device configured to connect a vessel to a framework and a connection system including the insulated clamping device, where the vessel includes the aforementioned insulation arrangement.

A method for displaying a fill level of a pressure vessel includes measuring an actual fill level of the pressure vessel, calculating a displayable fill level based on the actual fill level, and displaying the displayable fill level via a display device. In the method, during refueling between a first filling point (FP1) and a second filling point (FP2), the displayable fill level is increased in relation to the actual fill level in accordance with a predefined characteristic curve.