System and method for conducting enhanced oil recovery by establishing a plurality of stacked, alternating slugs of gas and liquid travelling downhole into a subterranean well. The system can include a buffer tank including a liquid inlet through which liquid is received from a liquids source into the buffer tank, a gas inlet through which gas is received from a pressured gas source into the buffer tank, a gas outlet in fluid communication with gas reservoired in the buffer tank, and a liquid outlet in fluid communication with liquid reservoired in the buffer tank. The system can further include a pressure control configured to maintain a specified pressure in gas reservoired within the buffer tank and a fluid dispensing system in fluid communication with the gas and liquid outlets of the buffer tank.

Systems, methods, and computer program products can be used for determining the amount of oil removed by a miscible gas flood. One of the methods includes identifying locations of oil within a volume representing a reservoir rock sample. The method includes identifying locations of gas within the volume. The method also includes determining the amount of oil removed based on locations within the volume where oil is either coincident with the gas or is connected to the gas by a continuous oil path.

The present invention finds its field of application among the advanced oil recovery methods, which must occur simultaneously and integrated with the capture, utilization, and storage of CO2 through a cavern built in offshore saline rock. More particularly the invention refers to offshore oil wells where there is an evaporitic rock layer next to it and, suitable for constructing a cavern in the saline rock, for its use as a CO2 and brine control volume in the water-gas alternating injection process in the reservoir.

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.

Disclosed are compositions and methods for the pressure protection of existing wells during infill drilling operations.

A system includes an oxidant compressor and a gas turbine engine turbine, which includes a turbine combustor, a turbine, and an exhaust gas compressor. The turbine combustor includes a plurality of diffusion fuel nozzles, each including a first oxidant conduit configured to inject a first oxidant through a plurality of first oxidant openings configured to impart swirling motion to the first oxidant in a first rotational direction, a first fuel conduit configured to inject a first fuel through a plurality of first fuel openings configured to impart swirling motion to the first fuel in a second rotational direction, and a second oxidant conduit configured to inject a second oxidant through a plurality of second oxidant openings configured to impart swirling motion to the second oxidant in a third rotational direction. The first fuel conduit surrounds the first oxidant conduit and the second oxidant conduit surrounds the first fuel conduit.

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.

A method of removing wellbore water from a production wellbore includes determining a production flow rate. The method also includes determining a target production flow rate of the production fluid and comparing the production flow rate to a flow rate threshold associated with the target production flow rate. The method also includes determining, based on a result of comparing the production flow rate to the flow rate threshold, that the production flow rate satisfies the threshold. The method also includes activating a fluid moving device fluidly coupled to a wellbore string extending from a terranean surface to the water to inject, into the water, at least one of i) a surfactant, ii) a gas, or iii) a foaming agent, allowing the water and the production fluid to emulsify together and thereby allowing a mixture of water and production fluid to flow to the terranean surface of the wellbore.

The application discloses foam compositions, methods to produce foam compositions, and methods to increase hydrocarbon production by displacing a hydrocarbon product with a foam composition. The foam composition includes an aqueous phase that typically includes an amphoteric surfactant and inorganic ions.

Disclosed techniques include a method of obtaining an enhanced oil recovery fluid from a hydrocarbon reservoir, comprising producing a hydrocarbon stream from the hydrocarbon reservoir, separating an associated gas stream from the hydrocarbon stream, and condensing at least a portion of the associated gas stream to obtain an enriched hydrocarbon fluid suitable for injecting into a liquid layer of the hydrocarbon reservoir to enhance recovery of hydrocarbons from the hydrocarbon reservoir.