A heat-insulating container being used under an environment where exposure to water of liquid is possible, includes a container main body having a substance holding portion which holds a substance at a temperature which is lower than a normal temperature on the inside of the substance holding portion; and a heat-insulating structure body which is provided in the container main body and includes at least a vacuum heat-insulating material. In addition, the vacuum heat-insulating material includes an outer cover material and an inner member sealed in a tightly closed and decompressed state on an inside of the outer cover material. In addition, the inner member is configured of a material which does not generate hydrogen in a case of coming into contact with the moisture of the liquid.

A vacuum heat-insulating material includes: an outer cover material; and a core material which is sealed in a tightly closed and decompressed state on the inside of the outer cover material. Outer cover material has gas barrier properties and satisfies at least one of a condition that a linear expansion coefficient is 8010.sup.5/ C. or lower when a static load is 0.05 N within a temperature range of 130 C. to 80 C., inclusive, a condition that an average value of a linear expansion coefficient is 6510.sup.5/ C. or higher when a static load is 0.4 N within a temperature range of 140 C. to 130 C., inclusive, a condition that an average value of a linear expansion coefficient is 2010.sup.5/ C. or higher when a static load is 0.4 N within a temperature range of 140 C. to 110 C., inclusive, and a condition that an average value of a linear expansion coefficient is 1310.sup.5/ C. or higher when a static load is 0.4 N within a temperature range of +50 C. to +65 C., inclusive.

A vacuum heat-insulating material includes: an outer cover material; and a core material which is sealed in a tightly closed and decompressed state on the inside of the outer cover material. Outer cover material has gas barrier properties and satisfies at least one of a condition that a linear expansion coefficient is 8010.sup.5/ C. or lower when a static load is 0.05 N within a temperature range of 130 C. to 80 C., inclusive, a condition that an average value of a linear expansion coefficient is 6510.sup.5/ C. or higher when a static load is 0.4 N within a temperature range of 140 C. to 130 C., inclusive, a condition that an average value of a linear expansion coefficient is 2010.sup.5/ C. or higher when a static load is 0.4 N within a temperature range of 140 C. to 110 C., inclusive, and a condition that an average value of a linear expansion coefficient is 1310.sup.5/ C. or higher when a static load is 0.4 N within a temperature range of +50 C. to +65 C., inclusive.

A method for subsurface gas storage including injecting a hydrogen stream into a subsurface reservoir for storage during periods of low sales demand, mixing the hydrogen stream in the subsurface reservoir with a stored gas, and removing the hydrogen from the subsurface reservoir during high sales demand.

Systems and method for controlling wellsite equipment, including pumps and a manifold having a low-pressure (LP) manifold, having LP ports with LP valves, and a high-pressure (HP) manifold, having HP ports with HP valves and bleed ports with bleed valves. The pumps are fluidly coupled with the LP manifold via LP conduits and with the HP manifold via HP conduits. Communication is established between a controller and the LP valves, the HP valves, the bleed valves, the pumps, and sensors for monitoring pressure within the HP conduits. The controller is operable to, with respect to each pump, cause the LP valve to transition to a closed position, cause the HP and/or bleed valve to transition to an open position, and determine that the HP conduit is not pressurized based on the information generated by the sensors.

A fuel delivery and storage method is provided. A further aspect employs a remote central controller and/or software instructions which receive sensor data from stationary and bulk fuel storage tanks, portable distribution tanks, and end use tanks. Another aspect of the present system senses and transmits tank or hydrogen fuel characteristics including temperature, pressure, filled volume, contaminants, refilling cycle life and environmental hazards. Still another aspect includes a group of hydrogen fuel tanks which is pre-assembled with sensor, valve, microprocessor and transmitter components, at least some of which are within an insulator.

A compressed gas energy storage system may include an accumulator for containing a layer of compressed gas atop a layer of liquid. A gas conduit may have an upper end in communication with a gas compressor/expander subsystem and a lower end in communication with accumulator interior for conveying compressed gas into the compressed gas layer of the accumulator when in use. A shaft may have an interior for containing a quantity of a liquid and may be fluidly connectable to a liquid source/sink via a liquid supply conduit. A partition may cover may separate the accumulator interior from the shaft interior. An internal accumulator force may act on the inner surface of the partition and the liquid within the shaft may exert an external counter force on the outer surface of the partition, whereby a net force acting on the partition is less than the accumulator force.

A fuel delivery and storage method is provided. A further aspect employs a remote central controller and/or software instructions which receive sensor data from stationary and bulk fuel storage tanks, portable distribution tanks, and end use tanks. Another aspect of the present system senses and transmits tank or hydrogen fuel characteristics including temperature, pressure, filled volume, contaminants, refilling cycle life and environmental hazards. Still another aspect includes a group of hydrogen fuel tanks which is pre-assembled with sensor, valve, microprocessor and transmitter components, at least some of which are within an insulator.

Hydrogen foams may be used for placing and maintaining hydrogen in a subterranean location. For example, methods for introducing hydrogen to a subterranean location may include: placing a hydrogen foam in a subterranean location, in which the hydrogen foam comprises a continuous phase generated from a foamable composition comprising an aqueous fluid and a discontinuous phase comprising at least hydrogen gas; and maintaining the hydrogen foam in the subterranean location.

Present embodiments relate generally to a cap for a pressure vessel. More specifically, but without limitations, present embodiments relate to a cap for a pressure vessel, for non-limiting example a submerged pipeline or other pressurized structure wherein the cap engages a flange and the assembly is removable to open the pressure vessel at the flange.