The present disclosure is directed toward a system and a method for storing gas. The system for storing gas comprises a salt formation, an overburden, an underburden, a salt cavern within the salt formation, a sorbent within the salt cavern, and a well traversing the surface that connects the surface with the salt cavern. The method for storing gas comprises several steps. A dissolving fluid comprising water is injected into a salt formation to produce a brine and a salt cavern within the salt formation. The brine is then removed from the salt cavern. A sorbent is then placed within the salt cavern before gas is injected into the salt cavern.

A method for operating a kerogen-rich unconventional gas reservoir characterized by there being multiple hydraulically-fractured wells drilled thereinto comprises: recovering a methane-containing gas from a first hydraulically-fractured well drilled into the gas reservoir, steam-methane reforming the recovered methane-containing gas to yield a hydrogen gas and an inorganic carbon-containing gas, injecting at least a portion of the hydrogen gas into a second hydraulically-fractured well drilled into the gas reservoir, and injecting at least a portion of the inorganic carbon-containing gas into a third hydraulically-fractured well drilled into the gas reservoir.

Systems and methods for managing flowback fluids produced during a flowback process in a well are provided. The system includes a well formed in a target zone in a hydrocarbon reservoir, where the well also extends to a disposal zone. The system also includes a check valve or zonal isolation systems. The method includes selecting a disposal zone, directing the formation of a well extending through a target zone and a disposal zone, transporting the flowback fluid from the target zone to the disposal zone during the flowback process, and selectively plugging the well near the disposal zone to prevent migration of the flowback fluid.

A method of separating gas from a fluid mixture in a production stream of a well where the method includes using an outer tube and an inner tube positioned concentrically with the outer tube to separate gas and liquid from a mixture. The production stream is directed through the outer tube and into a space between a well casing of the well and the outer tube where gas in the production stream can separate from fluid in the production stream. The separated fluid is then directed through the inner tube to a pump.

A submersible pump system may include a perforated casing lining a wellbore adjacent to a first formation and a second formation. Additionally, a production tubing may be hanging in the wellbore to extend past the first formation and into the second formation to form a fluid conduit from a surface to the second formation. Further, an electrical submersible pump may be coupled to the production tubing and be oriented upside-down to have one or more fluid intakes at an upper end of the electrical submersible pump and one or more fluid outlets at a lower end of the electrical submersible pump. The electrical submersible pump may be positioned downhole in the wellbore between the first formation and the second formation. The upside-down electrical submersible pump may be configured to extract fluid from the first formation and inject the extracted fluid into the second formation with the production tubing.

A method for operating a kerogen-rich unconventional gas reservoir characterized by there being multiple hydraulically-fractured wells drilled thereinto comprises: recovering a methane-containing gas from a first hydraulically-fractured well drilled into the gas reservoir, steam-methane reforming the recovered methane-containing gas to yield a hydrogen gas and an inorganic carbon-containing gas, injecting at least a portion of the hydrogen gas into a second hydraulically-fractured well drilled into the gas reservoir, and injecting at least a portion of the inorganic carbon-containing gas into a third hydraulically-fractured well drilled into the gas reservoir.

Techniques for managing water disposal include circulating a mixed water-oil liquid in a pipeline from a water-oil separation plant toward at least one disposal well that includes a wellbore formed from a terranean surface to a subterranean formation; determining, based on a sampling of the mixed water-oil liquid by an OIW meter, an amount of oil in the mixed water-oil liquid; based on the amount of oil being within a desired amount range: controlling each a choke valve and a surface safety valve to modulate toward an open position, and controlling a recycle valve to modulate to a closed position; and based on the amount of oil being outside of the desired amount range: controlling the choke valve and the surface safety valve to modulate toward a closed position, and controlling the recycle valve to modulate to an open position.

Techniques for managing water disposal include circulating a mixed water-oil liquid in a pipeline from a water-oil separation plant toward at least one disposal well that includes a wellbore formed from a terranean surface to a subterranean formation; determining, based on a sampling of the mixed water-oil liquid by an OIW meter, an amount of oil in the mixed water-oil liquid; based on the amount of oil being within a desired amount range: controlling each a choke valve and a surface safety valve to modulate toward an open position, and controlling a recycle valve to modulate to a closed position; and based on the amount of oil being outside of the desired amount range: controlling the choke valve and the surface safety valve to modulate toward a closed position, and controlling the recycle valve to modulate to an open position.

Disclosed herein are processes and systems for disposal of de-oiled algae bodies used for production of lipids and other bioproducts. An exemplary process may include providing a de-oiled algae body stream comprising de-oiled algae bodies, processing the de-oiled algae bodies by de-watering the de-oiled algae bodies, slurrying the de-oiled algae bodies with water to produce an algae body disposal stream, and then pumping the de-oiled algae bodies into a salt cavern.

A method for storing an energy-storage fluid within a subterranean formation having suppressed microbial activity includes injecting a high-salinity aqueous solution into the subterranean formation via at least one injection wellbore extending from a terranean surface and penetrating the subterranean formation, such that at least a portion of the high-salinity aqueous solution is held within the subterranean formation. The high-salinity aqueous solution includes water and an inorganic salt, and is configured to suppress microbial activity in the subterranean formation. The method also includes injecting the energy-storage fluid into the subterranean formation via the at least one injection wellbore to store at least a portion of the energy-storage fluid within the subterranean formation.