A method for enhanced oil recovery in a reservoir is provided. The method includes injecting a microsphere suspension, including polymeric microspheres dispersed in seawater, into an injection well in the reservoir and injecting a low salinity tailored water (SmartWater) into the injection well in the reservoir. Oil is produced from a production well in the reservoir.

A method for enhanced oil recovery in a reservoir is provided. The method includes injecting a microsphere suspension, including polymeric microspheres dispersed in seawater, into an injection well in the reservoir and injecting a low salinity tailored water (SmartWater) into the injection well in the reservoir. Oil is produced from a production well in the reservoir.

A first well, configured to act as a production well or an injection well, is formed. The first well includes a first horizontal portion. A second well, configured to act as a production well or an injection well, is formed. The second well includes a second horizontal portion substantially parallel to the first horizontal portion. The first horizontal portion and the second horizontal portion are at different depths. A fluid is injected into a geologic formation through the first well for a first duration of time. Hydrocarbons are produced from the geologic formation through the second well for the first duration of time. A fluid is injected into a geologic formation through the second well for a second duration of time. Hydrocarbons are produced from the geologic formation through the first well for the second duration of time.

A first well, configured to act as a production well or an injection well, is formed. The first well includes a first horizontal portion. A second well, configured to act as a production well or an injection well, is formed. The second well includes a second horizontal portion substantially parallel to the first horizontal portion. The first horizontal portion and the second horizontal portion are at different depths. A fluid is injected into a geologic formation through the first well for a first duration of time. Hydrocarbons are produced from the geologic formation through the second well for the first duration of time. A fluid is injected into a geologic formation through the second well for a second duration of time. Hydrocarbons are produced from the geologic formation through the first well for the second duration of time.

The present invention provides compositions and methods for enhancing oil recovery from low permeability subterranean formation using three mechanisms: repressurization; reduction of interfacial tension; and increased permeability. The subject compositions comprise a chelating agent, a biosurfactant, a carbonate or bicarbonate salt, water, and a pH adjusting substance, which when applied to an oil-bearing formation according to the methods of the subject invention, allow for controlled release of carbon dioxide within the formation without complicated machinery or gas-producing microorganisms.

The present invention provides compositions and methods for enhancing oil recovery from low permeability subterranean formation using three mechanisms: repressurization; reduction of interfacial tension; and increased permeability. The subject compositions comprise a chelating agent, a biosurfactant, a carbonate or bicarbonate salt, water, and a pH adjusting substance, which when applied to an oil-bearing formation according to the methods of the subject invention, allow for controlled release of carbon dioxide within the formation without complicated machinery or gas-producing microorganisms.

A method for enhanced oil recovery may comprise inputting into a computer system data related to properties of a hydrocarbon reservoir and depletion of the hydrocarbon reservoir; calculating, with the computer system, a current oil saturation and a current gas saturation of the hydrocarbon reservoir based on the data; determining, with the computer system, that the current reservoir pressure is less than a bubble point pressure based on the data; calculating, with the computer system, a time to repressure the hydrocarbon reservoir by waterflooding based on the data; comparing, with the computer system, the data related to properties of the hydrocarbon reservoir to oil recovery screening criteria; selecting a flooding technique from a plurality of flooding techniques, with the computer system, based on satisfying the oil recovery screening criteria with the data related to properties of the hydrocarbon reservoir.

A method for enhanced oil recovery may comprise inputting into a computer system data related to properties of a hydrocarbon reservoir and depletion of the hydrocarbon reservoir; calculating, with the computer system, a current oil saturation and a current gas saturation of the hydrocarbon reservoir based on the data; determining, with the computer system, that the current reservoir pressure is less than a bubble point pressure based on the data; calculating, with the computer system, a time to repressure the hydrocarbon reservoir by waterflooding based on the data; comparing, with the computer system, the data related to properties of the hydrocarbon reservoir to oil recovery screening criteria; selecting a flooding technique from a plurality of flooding techniques, with the computer system, based on satisfying the oil recovery screening criteria with the data related to properties of the hydrocarbon reservoir.

An object of the disclosure is to determine the remaining saturation of existing fluids in naturally fractured and/or homogeneous reservoirs, considering an unconventional tracer test, using the double tracer test method with pressure monitoring (PDTcMP®), which also integrates unused technical elements, in order to estimate more accurately the value of the remaining oil saturation (ROS) in naturally fractured reservoirs, unlike conventional methods used most commonly in homogeneous media. The disclosure substantially modifies the conventional tracer test, as it uses innovative technical elements, which reduce the uncertainty and/or ambiguity associated with conventional tracer tests, when they are applied in naturally fractured reservoirs.

An object of the disclosure is to determine the remaining saturation of existing fluids in naturally fractured and/or homogeneous reservoirs, considering an unconventional tracer test, using the double tracer test method with pressure monitoring (PDTcMP®), which also integrates unused technical elements, in order to estimate more accurately the value of the remaining oil saturation (ROS) in naturally fractured reservoirs, unlike conventional methods used most commonly in homogeneous media. The disclosure substantially modifies the conventional tracer test, as it uses innovative technical elements, which reduce the uncertainty and/or ambiguity associated with conventional tracer tests, when they are applied in naturally fractured reservoirs.