Abstract: The present disclosure details methods and systems for generating and recovering hydrogen from a depleted reservoir. The methods comprise several steps. Oxygen is introduced into a depleted reservoir. A fire flood is initiated, increasing temperature in the depleted reservoir and generating a gas mixture. The gas mixture is removed and transported to the surface. Energy is recovered from the gas mixture. Hydrogen is separated from the gas mixture, producing a depleted gas mixture and a hydrogen-rich gas mixture. The hydrogen-rich gas mixture is introduced into a subterranean storage formation.

Abstract: A core holder for core testing includes a body having a cavity. A sleeve is disposed within the cavity. The sleeve defines a chamber to hold one or more core plugs. One or more fiber-optic sensors are disposed at a perimeter of the chamber. Each fiber-optic sensor senses a parameter related to flow of fluid through the chamber. A core testing system includes one or more light sources to provide light to each fiber-optic sensor and one or more light detectors to detect light from each fiber-optic sensor. A method of core testing may include injecting a fluid into one or more core plugs inside the chamber and measuring one or more parameters related to flow of fluid through the one or more core plugs.

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: A fluid processing system is configured for use in a wellbore in a hydrocarbon-bearing rock formation. The system includes a casing liner disposed in an open hole section of a well for providing a separation zone in a flow of materials from a first reservoir The system includes a downhole separator operatively coupled to the casing liner for separating the first material and the second material within the flow of materials. The flow of materials includes at least a first material and a second material.

Abstract: A method may include obtaining reservoir data for a geological region of interest. The method may further include obtaining turbine data regarding a supercritical carbon dioxide power (sCO2) turbine. The method may further include obtaining carbon emission data for a well coupled to the geological region of interest. The method may further include determining predicted production data and predicted carbon emission data using a machine-learning model, the reservoir data, the turbine data, and the carbon emission data. The method may further include transmitting a command to a control system based on the predicted production data and the predicted carbon emission data. The command may adjusts an amount of carbon dioxide that is distributed to an injection well and the sCO2 turbine. The command achieves a predetermined production rate at the well and a predetermined carbon footprint.

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 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 system for a carbon neutral cycle of gas production includes a molten salt reactor configured to generate zero carbon dioxide (CO2) emissions electricity. The system includes a desalination unit configured to receive the zero-CO2 emissions electricity from the molten salt reactor and produce a desalinated water. The system includes an electrolysis unit configured to be powered by the zero-CO2 emissions electricity generated by the molten salt reactor and generate hydrogen (H2) and oxygen (O2) from the desalinated water. The system includes an oxy-combustion unit configured to receive and combust a hydrocarbon fuel with the O2 from the electrolysis unit to produce electricity and CO2. The system includes a CO2 capture system adapted to capture the CO2 produced by the oxy-combustion unit and a catalytic hydrogenation unit configured to receive and convert H2 from the electrolysis unit and CO2 from the CO2 capture system to produce the hydrocarbon fuel.

Abstract: Systems and methods for improving injectivity of a hydrocarbon reservoir include: identifying a restriction of flow from an injection well into the hydrocarbon reservoir; transmitting a series of acoustic waves from an injection well into a formation that includes the hydrocarbon reservoir, wherein the series of acoustic waves are transmitted continuously for at least one day; transmitting a series of seismic waves from the injection well into the formation after the series of acoustic waves are transmitted into the hydrocarbon reservoir, wherein the series of seismic waves are transmitted continuously for at least one week; and injecting water into the injection well to cause hydrocarbon of the hydrocarbon reservoir to flow from the hydrocarbon reservoir to a production well after the series of acoustic waves are transmitted into the hydrocarbon reservoir.

Abstract: A logging system for a tubular includes: a rail system comprising a plurality of rails and mounted to a surface of the tubular; a logging tool carrier connected to the rail system; and a logging tool disposed on the logging tool carrier. The logging tool is deployed on the logging tool carrier connected to the rail system along the tubular to a targeted position along the tubular and then retrieved from the wellbore. During deployment of the logging tool, the logging tool acquires a plurality of logging data.

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.

Abstract: A method of mitigating lost circulation in a subterranean wellbore for oil and gas includes introducing basaltic particles and a carbonated mixture to the lost circulation 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, reacting divalent cations with the carbonate anions in the carbonated mixture to produce carbonate minerals, providing stimulus to the basaltic particles and the carbonated mixture, depositing at least a part of the carbonate minerals to fractures of the lost circulation zone, monitoring the reacting and depositing; and optionally repeating one or more of the aforementioned steps. A drilling system for oil and gas extraction includes basaltic particles, a carbonated mixture, at least one stimulus generator, and a mitigation device.

Abstract: An example CO2 monitoring systems is configured for monitoring levels of CO2 in a wellbore. A CO2 monitoring system may include one or more laser monitoring tools. A laser monitoring tool may include an optical element to output a laser beam, a detector to receive the laser beam, a first chamber housing the optical element and detector, and a second chamber including an inlet and an outlet receive and release, respectively, wellbore fluid. The first chamber may be in fluid connection with second chamber via a gas permeable membrane. Gas may permeate from second chamber into first chamber. Gas in the first chamber is subjected to a laser beam. Absorption of light by the gas is measured, and content of gas is determined based at least in part on the amount of light absorption by the gas.

Abstract: A system for a carbon neutral cycle of gas production may include a molten salt reactor configured to generate zero carbon dioxide (CO2) emissions electricity. The system may include a desalination unit configured to receive the zero-CO2 emissions electricity from the molten salt reactor and produce a desalinated water. The system may include an electrolysis unit configured to be powered by the zero-CO2 emissions electricity generated by the molten salt reactor and generate hydrogen (H2) and oxygen (O2) from the desalinated water. The system may include an oxy-combustion unit configured to receive and combust a hydrocarbon fuel with the O2 from the electrolysis unit to produce electricity and CO2. The system may include a CO2 capture system adapted to capture the CO2 produced by the oxy-combustion unit and a catalytic hydrogenation unit configured to receive and convert H2 from the electrolysis unit and CO2 from the CO2 capture system to produce the hydrocarbon fuel.

Abstract: A fluid processing system is configured for use in a wellbore in a hydrocarbon-bearing rock formation. The system includes a casing liner disposed in an open hole section of a well for providing a separation zone in a flow of materials from a first reservoir The system includes a downhole separator operatively coupled to the casing liner for separating the first material and the second material within the flow of materials. The flow of materials includes at least a first material and a second material.

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 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 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 logging system for a tubular includes: a rail system comprising a plurality of rails and mounted to a surface of the tubular; a logging tool carrier connected to the rail system; and a logging tool disposed on the logging tool carrier. The logging tool is deployed on the logging tool carrier connected to the rail system along the tubular to a targeted position along the tubular and then retrieved from the wellbore. During deployment of the logging tool, the logging tool acquires a plurality of logging data.

Abstract: According to one or more embodiments of the present disclosure, water-based drilling fluids may include an aqueous base fluid and one or more additives. In embodiments, water-based drilling fluids may include a lubricant blend including at least oleic acid and palmitoleic acid. The sum of the volume percent of the oleic acid and palmitoleic acid may be from 0.1 vol. % to 10 vol. % of the total volume of the water-based drilling fluid. In embodiments, water-based drilling fluids may include a lesser melting point fraction of jojoba oil in an amount of from 0.1 vol. % to 10 vol. % relative to the total volume of the water-based drilling fluid. At least 90% of the lesser melting point fraction of jojoba oil may have a melting point less than or equal to 15° C. Methods for drilling subterranean wells with the water-based drilling fluids are also disclosed.