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 dispersion of capsules in critical or supercritical carbon dioxide is provided. The capsules include an aqueous solution encapsulated by 2-dimensional particles. Also provided is a method of 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. Associated methods of using the disclosed dispersions in hydrocarbon-bearing formations are also provided.

Abstract: A method includes providing an injection well extending from a surface into a formation and alternatingly pumping a foam injectant and a gel injectant into the injection well, wherein the foam injectant includes a liquid phase with a surfactant and water and a gas phase and the gel injectant includes a water-soluble polymer and a crosslinker. The foam injectant and the gel injectant are injected at separate times and sequentially.

Abstract: A downhole monitoring system for continuously measuring in real-time a fluid produced from a reservoir includes a tubing extending into a wellbore, spaced apart packers forming annular seals between the tubing and a wall of the wellbore, isolated compartments formed between the spaced apart packers, each compartment having an opening in the tubing to allow fluid communication from the reservoir to surface equipment, and an ultraviolet spectrometer installed in each compartment. The ultraviolet spectrometer includes an ultra-violet source that excites diamondoids, a photomultiplier to quantify the excited diamondoids, and an electronic circuit that digitizes a response from the photomultiplier and sends the response to the surface of the wellbore. Additionally, a method includes continuously monitoring and in real-time a fluid produced from a reservoir and determining reservoir connectivity and reservoir profiling.

Abstract: A illustrative surface carbon capture and storage system includes a treatment and separation facility that receives CO2 containing fluid and extracts CO2 from the CO2 containing fluid. A compressor downstream of the treatment and separation facility compresses the extracted CO2 into compressed CO2, which is introduced further downstream to a reaction container along with water, and other reactants. A method for surface carbon capture and storage includes separating CO2 from a CO2 containing fluid and compressing the separated CO2. The compressed CO2, along with water, and other reactants is introduced into a reaction container where the CO2 mineralizes. The mineralized CO2 is outputted from the reaction container.

Abstract: A dispersion of capsules in critical or supercritical carbon dioxide is provided. The capsules include an aqueous solution encapsulated by magnetic covalent organic framework particles. Also provided is a method of 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 magnetic covalent organic framework particle into the critical or supercritical carbon dioxide medium. Associated methods of using the disclosed dispersions in hydrocarbon-bearing formations are also provided.

Abstract: A method may include obtaining reservoir data for a geological region of interest. The method may further include obtaining production data regarding one or more wells coupled to the geological region of interest. The method may further include obtaining carbon emission data for the one or more wells. The method may further include determining predicted carbon emission data and predicted production data using a machine-learning model. The method may further include determining one or more stimulation parameters for a stimulation operation based on the predicted carbon emission data and the predicted production data. The method may further include transmitting a command to a control system coupled to an injection well. The command adjusts an amount of carbon dioxide that is supplied to the injection well based on the one or more stimulation parameters.

Abstract: A dispersion of capsules in critical or supercritical carbon dioxide is provided. The capsules include an aqueous solution encapsulated by covalent organic framework particles. Also provided is a method of 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 covalent organic framework particle into the critical or supercritical carbon dioxide medium. Associated methods of using the disclosed dispersions in hydrocarbon-bearing formations are also provided.

Abstract: A method for optimizing a wireless sensor network for monitoring hydrogen production from fire flooding involves training a machine learning model to generate an estimate of communication performance of each of a multitude of sensors. The sensors are a component of the wireless sensor network disposed in a sub-surface hydrogen reservoir, with each of the multitude of sensors configured to obtain measurements of environmental variables of the hydrogen reservoir. The method further involves minimizing a cardinality of the multitude of sensors, using the machine learning model.

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 method for enhancing productivity of a stratified subterranean wellbore includes introducing a mixture including water and a first set of nanoparticles reactive to high frequency acoustic waves having a size ranging from about 10 to 100 nm to a first target zone, located in a high permeability layer of the stratified subterranean wellbore. A first stimulation including acoustic waves having a frequency range of 1 kHz to 10 kHz is provided to the first set of nanoparticles to promote reacting. Then, a mixture including water and a second set of nanoparticles having a size ranging from about 1 to 10 nm is introduced to a second target zone, located in a medium permeability layer of the stratified subterranean wellbore. A second stimulation including acoustic waves having a frequency range of 100 Hz to 1 kHz is provided to the second set of nanoparticles to promote reacting.

Abstract: A downhole monitoring system for continuously measuring in real-time a fluid produced from a reservoir includes a tubing extending into a wellbore, spaced apart packers forming annular seals between the tubing and a wall of the wellbore, isolated compartments formed between the spaced apart packers, each compartment having an opening in the tubing to allow fluid communication from the reservoir to surface equipment, and an ultraviolet spectrometer installed in each compartment. The ultraviolet spectrometer includes an ultra-violet source that excites diamondoids, a photomultiplier to quantify the excited diamondoids, and an electronic circuit that digitizes a response from the photomultiplier and sends the response to the surface of the wellbore. Additionally, a method includes continuously monitoring and in real-time a fluid produced from a reservoir and determining reservoir connectivity and reservoir profiling.

Abstract: In accordance with one or more embodiments of the present disclosure, an acidizing fluid suitable for use in acid treatment of subterranean formations includes an aqueous base fluid, an acid, and a surfactant comprising an oil mixture. The oil mixture comprises no more than 5% by volume of the acidizing fluid. Also described are methods of improving hydrocarbon recovery from a subterranean formation.

Abstract: A well system is provided that includes an injection wellbore having a configuration that traverses an injection formation and has a horizontal configuration. The injection wellbore also has a configuration such that a treatment fluid and a CO2 fluid may be introduced into the injection wellbore and also selectively introduced into a treatment zone. The treatment fluid comprises water and basalt nanoparticles. The injection wellbore has a configuration such that the treatment zone is positioned in a horizontal portion of the injection wellbore. Each treatment zone includes a treatment unit. The treatment unit is configured to selectively introduce a fluid into the treatment zone. The treatment zone is in fluid communication with the injection formation. A method for treating an injection formation includes introducing a treatment fluid into a well system as previously described, selectively introducing the treatment fluid into a treatment zone, and monitoring the injection formation.

Abstract: A illustrative process for quantifying CO2 sequestration within a reservoir includes, among other things, measuring a cumulative amount of CO2 injected into a reservoir via injection wells and at a CO2 storage plant, measuring the cumulative amount of CO2 produced via production wells and at a processing plant, estimating a cumulative amount of CO2 migrated from a reservoir based on measured CO2 via observations wells, and calculating a net amount of CO2 remaining in the reservoir based on the cumulative amount of CO2 injected, CO2 produced, and the CO2 that has migrated. An illustrative CO2 quantifying and sequestration system includes, among other things, injection wells, production wells, observation wells, measurement devices for measuring an amount of CO2 injected, observed and produced, and a measurement collection and analysis system for receiving signals from the measurement devices and for estimating an amount of CO2 sequestered within the reservoir.

Abstract: A well system is provided that includes an injection wellbore having a configuration that traverses an injection formation and has a horizontal configuration. The injection wellbore also has a configuration such that a treatment fluid and a CO2 fluid may be introduced into the injection wellbore and also selectively introduced into a treatment zone. The treatment fluid comprises water and basalt nanoparticles. The injection wellbore has a configuration such that the treatment zone is positioned in a horizontal portion of the injection wellbore. Each treatment zone includes a treatment unit. The treatment unit is configured to selectively introduce a fluid into the treatment zone. The treatment zone is in fluid communication with the injection formation. A method for treating an injection formation includes introducing a treatment fluid into a well system as previously described, selectively introducing the treatment fluid into a treatment zone, and monitoring the injection formation.

Abstract: A foam for hydrocarbon recovery includes a gas phase and a liquid phase. The liquid phase includes a foaming mixture, and the foaming mixture includes an aqueous solution, one or more surfactants, and an oil mixture. At least 2 wt. % of the liquid phase includes the oil mixture. Also described are methods of recovering hydrocarbons from a deposit reservoir using such a foam, as well as a hydrocarbon well including such a foam.

Abstract: A method for enhancing productivity of a stratified subterranean wellbore includes introducing a mixture including water and a first set of nanoparticles reactive to high frequency acoustic waves having a size ranging from about 10 to 100 nm to a first target zone, located in a high permeability layer of the stratified subterranean wellbore. A first stimulation including acoustic waves having a frequency range of 1 kHz to 10 kHz is provided to the first set of nanoparticles to promote reacting. Then, a mixture including water and a second set of nanoparticles having a size ranging from about 1 to 10 nm is introduced to a second target zone, located in a medium permeability layer of the stratified subterranean wellbore. A second stimulation including acoustic waves having a frequency range of 100 Hz to 1 kHz is provided to the second set of nanoparticles to promote reacting.

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: A well bore logging tool for measuring a pore fluid property of a hydrocarbon reservoir that may include, a tool housing, a vessel containing a tracer, a launcher attached to the vessel that may be configured to inject a tracer into the hydrocarbon reservoir. The well bore logging too may further include a retrieval device configured to extract at least a portion of the tracer from the hydrocarbon reservoir. The well bore logging too may further include a storage canister may be configured to store a portion of the tracer extracted from the hydrocarbon reservoir, and a scanning device may be configured to read a value of at least one fluid saturation property detected by the tracer. The vessel, launcher, retrieval device, storage canister, and scanning device may be enclosed in a tool housing.