Abstract: 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.

Abstract: Hydrocarbon extraction may be coupled with subterranean hydrogen storage.

Abstract: A method for stimulating hydrogen production from an injection formation. This method includes the steps of providing a well traversing a subsurface into an injection formation containing hydrocarbons. Carbon dioxide, water, steam, and combustion gas are introduced into the injection formation via the well. Further, the injection formation is stimulated using one or more of infrasonic, sonic, and ultrasonic stimulation. The injection formation is monitored via one or more sensors located in the injection formation to determine one or more properties of reactions in the injection formation and the flow back effluent. Flowback operations are conducted to retrieve flowback effluent.

Abstract: A method for stimulating a reservoir includes providing a well traversing a subsurface into a reservoir containing hydrocarbons. Carbon dioxide and steam may be introduced into the reservoir via the well. The reservoir may be stimulated using one or more of infrasonic, acoustic, and ultrasonic stimulation. Seismic analyses may be applied to determine changes in flow characteristics of the reservoir. Monitoring a flow back effluent via one or more sensors located in the well may determine one or more properties of the flow back effluent. The introduction of carbon dioxide and steam, stimulating, and applying seismic may be repeated until a desired property of the flow back effluent is achieved. The method may include introducing hot carbonated water, carbon dioxide, and cold carbonated water into the reservoir via the well.

Abstract: Methods of enhancing productivity of a subterranean wellbore may include introducing a carbonated mixture comprising water and carbonate anions to a target zone of the subterranean wellbore; introducing basaltic particles to the target zone of the subterranean wellbore; contacting the basaltic particles with the carbonated mixture; dissolving at least a part of the basaltic particles with the carbonated mixture to release divalent cations including calcium cations, magnesium cations and ferrous cations; reacting, in the target zone of the subterranean wellbore, the divalent cations with the carbonate anions in the carbonated mixture to produce carbonate minerals; providing stimulus to the basaltic particles and the carbonated mixture to promote the dissolving and the reacting; depositing at least a part of the carbonate minerals to fractures of the target zone; and monitoring the reacting of the divalent cations with the carbonated anions and depositing.

Abstract: Embodiments disclosed relate to a method for producing, storing, and transporting a hydrogen gas as a liquid hydrogen fuel. The method includes using sand as a thermal energy storage medium for absorbing, storing, and transferring energy from an energy source to produce a power source, providing the power source to a water electrolysis process to produce a hydrogen gas and an oxygen gas, and the hydrogen gas may be send to a hydrogenation plant to produce liquid hydrogen fuel, and transporting the liquid hydrogen fuel via a transportation system from the hydrogenation plant to a point of consumption.

Abstract: 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.

Abstract: A method for stimulating a reservoir includes providing a well traversing a subsurface into a reservoir containing hydrocarbons. Carbon dioxide and steam may be introduced into the reservoir via the well. The reservoir may be stimulated using one or more of infrasonic, acoustic, and ultrasonic stimulation. Seismic analyses may be applied to determine changes in flow characteristics of the reservoir. Monitoring a flow back effluent via one or more sensors located in the well may determine one or more properties of the flow back effluent. The introduction of carbon dioxide and steam, stimulating, and applying seismic may be repeated until a desired property of the flow back effluent is achieved. The method may include introducing hot carbonated water, carbon dioxide, and cold carbonated water into the reservoir via the well.

Abstract: A method for demonstrating the efficacy of using electrical current in an Electrical Improved Oil Recovery (EIOR) application includes circulating fluid through a microfluidics cell having first and second electrodes, applying a voltage across the first and second electrodes, determining the behavior of the fluid under the effect of the applied voltage, and correlating the determined behavior to a reservoir of interest. The method may include deriving operational parameters from the correlation and operating the reservoir of interest in accordance with the operational parameters, and may include visualization and characterization of enlarging pore throat for enhancing permeability and oil mobilization.

Abstract: Methods for purifying a fluid may include injecting an impure fluid comprising carbon dioxide and at least one impurity into a first subterranean aquifer. The impure fluid may be circulated within the first subterranean aquifer for a period of time sufficient to separate at least a portion of the at least one impurity from the carbon dioxide to produce an at least partially purified fluid comprising the carbon dioxide, the at least partially purified fluid having a lower concentration of the at least one impurity than the impure fluid. The at least partially purified fluid may be removed from the first subterranean aquifer, wherein at least a portion of the at least one impurity remains entrained within the first subterranean aquifer.

Abstract: A composition includes a carbon dioxide (CO2) emulsion including a continuous critical or supercritical CO2 phase and a discontinuous phase including a polyacrylate. A method of making a CO2 emulsion includes providing a first solution of a polyacrylic acid and critical or supercritical CO2, providing a second solution of a base and critical or supercritical CO2, and mixing the first solution and the second solution such that the polyacrylic acid and the base react to form an emulsion of polyacrylate droplets in critical or supercritical CO2. A method of treating a hydrocarbon-bearing formation includes introducing an emulsion including a continuous CO2 phase and a discontinuous phase comprising a polyacrylate into the formation, contacting the emulsion with an aqueous reservoir fluid in the hydrocarbon-bearing formation, and absorbing an amount of the aqueous reservoir fluid into the polyacrylate of the emulsion to provide a dense CO2 emulsion.

Abstract: A dispersion includes capsules in critical or supercritical carbon dioxide and does not include a surfactant. The capsules include an aqueous solution encapsulated by 2-dimensional particles. A method includes making a dispersion of aqueous solution capsules. The method includes providing a medium of critical or supercritical carbon dioxide, introducing the aqueous solution into the critical or supercritical carbon dioxide medium, and introducing a 2-dimensional particle into the critical or supercritical carbon dioxide medium. The medium does not include a surfactant. Associated methods include using the disclosed dispersions in hydrocarbon-bearing formations.

Abstract: A tubing string is disposed within a wellbore to be in fluid communication with a reservoir. One or more inflow control devices are provided in the tubing string to receive well fluids produced from the reservoir. The one or more inflow control devices include a chamber in fluid communion with the tubing string. An inflow control valve is disposed in the chamber. The inflow control valve is configured to regulate a flow of the well fluids entering the tubing string based on a ratio of hydrocarbons to water. A control system is coupled to the inflow control valve. A plurality of sensors is on the tubing string and in communication with the control system to measure well data within the wellbore. The control system receives the well data to create commands to adjust a valve state of the inflow control valve corresponding with a required production rate of a well.

Abstract: A method for subsurface sequestration of carbon in a subterranean zone includes forming a fluid-filled volume in the subterranean zone by injecting an aqueous into the subterranean zone and injecting a mixture comprising silicate nanoparticles suspended in an acidic solution having a pH of less than 4. Carbon in the form of carbon dioxide is injected into the fluid-filled volume such that a least a portion of the carbon is sequestered by precipitation of carbonate minerals. At least a portion of the carbonate minerals are formed from reaction of metal cations with bicarbonate formed from the carbon dioxide, and least a portion of the metal cations are a product of decomposition of the silicate nanoparticles in the acidic solution.

Abstract: A system for sequestering greenhouse gas (GHG) in space includes at least one gas removal station located in or above an upper atmosphere, and a GHG transporter configured to collect the GHG from a GHG source and deliver the GHG to the gas removal station. The gas removal station includes a base configured to provide power and propulsion for gas removal station, a suction pump disposed on the base, and a GHG ejector disposed on the base and in fluid communication with the suction pump. The GHG ejector is configured to eject GHG at or above an escape velocity. A method for sequestering GHG to space includes collecting GHG from a GHG source, transporting GHG from the GHG source to a GHG ejection site located in or above an upper atmosphere, and ejecting GHG from the GHG ejection site at or above an escape velocity.

Abstract: A wellbore tubular including a pre-installed data transmission cable is disclosed. The tubular includes a hollow cylinder, a stationary ring disposed at the lower end of the cylindrical wall and having a lower end hollow pin protruding downward from the stationary ring, a rotating ring disposed at the upper end of the cylindrical wall and having an upper end hollow pin protruding upward from the rotating ring, a rigid conduit disposed inside the hollow cylinder and extending from the lower end hollow pin to beneath the rotating ring, a elastic conduit disposed inside the hollow cylinder to extend the rigid conduit from beneath the rotating ring to the upper end hollow pin, and a data transmission cable routed from the lower end hollow pin to the upper end hollow pin through the rigid conduit and the elastic conduit.

Abstract: A system for electrical treatment in a reservoir with gas wells is disclosed. The system includes a first well in the reservoir configured to act as an electrode, the reservoir having a plurality of pore spaces saturated by water, and a second well in the reservoir configured to act as a second electrode hydraulically connected to the first well. A power unit is connected to the first and second wells by a cable configured to emit an electric current to the first well and the second well into the reservoir. The electric current enlarges the plurality of pore spaces in the reservoir, facilitating a production of gas from the water. A transformer is connected to the power unit by the cable, the transformer being configured to step down a voltage from a power supply to the power unit. The power supply is connected to the transformer by the cable.

Abstract: A method for subsurface sequestration of carbon in a subterranean zone includes forming a fluid-filled volume in the subterranean zone by injecting an aqueous into the subterranean zone and injecting a mixture comprising silicate nanoparticles suspended in an acidic solution having a pH of less than 4. Carbon in the form of carbon dioxide is injected into the fluid-filled volume such that a least a portion of the carbon is sequestered by precipitation of carbonate minerals. At least a portion of the carbonate minerals are formed from reaction of metal cations with bicarbonate formed from the carbon dioxide, and least a portion of the metal cations are a product of decomposition of the silicate nanoparticles in the acidic solution.

Abstract: A method of enhancing heat transfer and energy efficiency in a geothermal reservoir includes injecting a carbonated fluid to the reservoir, injecting a first salt solution and a second salt solution into the reservoir, and increasing the temperature of the reservoir by reacting the first salt solution with the second salt solution to provide heat. The carbonated fluid injection decreases a temperature of the reservoir. The second salt solution is reactive with the first salt solution under the conditions in the reservoir after the injecting. A system of enhancing heat transfer and energy efficiency in a geothermal reservoir includes an injection system in fluid communication with an injection well. The injection system is configured to alternate the injection of the carbonated fluid and the first salt solution and second salt solution.

Abstract: Systems and methods for monitoring a hydrocarbon reservoir for escaped CO2 are disclosed. The methods include deploying a plurality of CO2 i-Bot sensors downhole into an observation well located above a CO2 injection zone, establishing communication among the plurality of CO2 i-Bot sensors, between the plurality of CO2 i-Bot sensors and a base station, and between the base station and a central processing location. The methods also include collecting a plurality of environmental data and sensor data from the plurality of CO2 i-Bot sensors, and training a machine learning algorithm to predict the plurality of environmental data and sensor data of the plurality of CO2 i-Bot sensors. Furthermore, the methods include determining an optimized number of CO2 i-Bot sensors that minimizes a quantity of power consumption and maximizes an area of coverage of the hydrocarbon reservoir by the plurality of CO2 i-Bot sensors using the trained machine learning algorithm.