A chelating agent can be used to enhance secondary hydrocarbon-fluid recovery during waterflooding operations. A composition can include a fluid and a chelating agent. The chelating agent can increase the viscosity of the fluid, which can enhance the efficacy of the waterflooding operations. The chelating agent can also form complexes with divalent cations in precipitates and solids formed by the divalent cations. The complexes can keep the cations in a soluble form until the composition exits the production well, which can prevent precipitates from forming in the production well and blocking pore throats in the production well.

The flow control device comprises one or more stacked spiral paths where the shape of an inlet to an end of a spiral has a taper on one or more sides to gradually increase the polymer velocity to eliminate rapid acceleration points as the flow enters the spiral path. The entrance with its taper can be curved to get into the spiral. The spiral can be entered tangentially or radially or axially.

A method for oil recovery by calculating, with a computer system, a current oil saturation of a reservoir, comparing, with the computer system, reservoir properties to screening criteria, determining, with the computer system, a minimum miscibility pressure based on correlations between the reservoir properties and the screening criteria; determining, with the computer system, if the minimum miscibility pressure is greater than a bubble point pressure of the reservoir and is less than or equal to an initial reservoir pressure, determining, with the computer system, a time to repressure the reservoir with water injection, performing a reservoir simulation with the computer system, and flooding the reservoir.

A method for oil recovery by calculating, with a computer system, a current oil saturation of a reservoir, comparing, with the computer system, reservoir properties to screening criteria, determining, with the computer system, a minimum miscibility pressure based on correlations between the reservoir properties and the screening criteria; determining, with the computer system, if the minimum miscibility pressure is greater than a bubble point pressure of the reservoir and is less than or equal to an initial reservoir pressure, determining, with the computer system, a time to repressure the reservoir with water injection, performing a reservoir simulation with the computer system, and flooding the reservoir.

The present disclosure relates to surfactants and methods used to increase hydrocarbon recovery from subterranean formations. Novel surfactant compositions are provided. In certain embodiments, the composition is a mixture of a sulfonated primary surfactant, water, and cosurfactants (anionic, zwitterionic/amphoteric or non-ionic surfactant). Methods to use these surfactant compositions to recover oil from formations using processes such as improved oil recovery (IOR) and flow-back processes are also provided.

A method and compounds for enhanced oil recovery (EOR) including flooding of a mixture of water and one or more of the compounds in a geological formation. The compounds have a fluoroalkyl group.

A method and compounds for enhanced oil recovery (EOR) including flooding of a mixture of water and one or more of the compounds in a geological formation. The compounds have a fluoroalkyl group.

A method is provided. Cells of a digital model of a formation are classified corresponding with one or more classes based on minerals and/or pore sizes. Wettability of the formation in the digital model is calibrated based on imbibition and/or drainage curves from physical experimentation for a rock sample and the one or more classes of the cells of the digital model.

A method is provided. Cells of a digital model of a formation are classified corresponding with one or more classes based on minerals and/or pore sizes. Wettability of the formation in the digital model is calibrated based on imbibition and/or drainage curves from physical experimentation for a rock sample and the one or more classes of the cells of the digital model.

The present invention relates to methods for recovering hydrocarbons from subterranean formations. One such example embodiment injects a polymer solution into an upper layer of a subterranean formation and, likewise, injects an aqueous solution into a lower layer of the subterranean formation. Hydrocarbons displaced by at least one of the injected polymer and the injected aqueous solution are collected.