Abstract: Methods for evaluating an optimal surfactant structure for oil recovery by systematically evaluating surfactants' phase behavior, cloud point, dynamic interfacial tension, dynamic contact angle, and spontaneous and forced imbibition. In one embodiment, a method for determining an optimal surfactant structure for oil recovery includes the steps of evaluating a surfactant's phase behavior, evaluating the surfactant's solubility, evaluating the surfactant's dynamic interfacial tension in a porous rock sample, evaluating the surfactant's static and dynamic contact angles in the porous rock sample, evaluating the surfactant's spontaneous imbibition in the porous rock sample, and evaluating the surfactant's forced imbibition in the porous rock sample. In one example, the surfactant comprises a polyoxyethylenated (POE) straight-chain alcohol.

Abstract: The present invention relates to a nanocondensation apparatus comprising a mass comparator, a core holder, an environmental chamber, and a pump and to methods for studying a fluid-solid system with the nanocondensation apparatus.

Abstract: The present invention relates to methods for evaluating an optimal surfactant structure for oil recovery by systematically evaluating surfactants' phase behavior, cloud point, dynamic interfacial tension, dynamic contact angle, and spontaneous and forced imbibition.

Abstract: Methods for determining an optimal surfactant structure for oil recovery are described. These methods systematically evaluate surfactants' phase behavior at ambient and at reservoir conditions; cloud point from ambient to reservoir conditions; dynamic interfacial tension at ambient and at reservoir conditions, including crude oil bubble images and fitting drop profiles; static contact angles at ambient conditions and dynamic contact angles at reservoir conditions; spontaneous imbibition at ambient conditions; and forced imbibition at reservoir conditions.

Abstract: Methods for determining an optimal surfactant structure for oil recovery are described. These methods systematically evaluate surfactants' phase behavior at ambient and at reservoir conditions; cloud point from ambient to reservoir conditions; dynamic interfacial tension at ambient and at reservoir conditions, including crude oil bubble images and fitting drop profiles; static contact angles at ambient conditions and dynamic contact angles at reservoir conditions; spontaneous imbibition at ambient conditions; and forced imbibition at reservoir conditions.

Abstract: The present invention relates to a nanocondensation apparatus comprising a mass comparator, a core holder, an environmental chamber, and a pump and to methods for studying a fluid-solid system with the nanocondensation apparatus.

Abstract: Novel microemulsion formulations comprising a surfactant or combination of surfactants are disclosed for improved crude oil cleanup or recovery from subsurface geological formations, especially those containing carbonate cements.

Abstract: An apparatus and method for simulating production conditions in hydrocarbon-bearing reservoirs, as an example, by flooding of core samples from such reservoirs, are described. Full recirculation flow measurements permit several fluids (for example, crude oil, brine, and gas) to be simultaneously injected into core samples having varying dimensions. Accurate and stable back pressures are maintained at total flow rates of as high as 200 cc/min., for a large range of fluid viscosities. Accurate and stable net overburden pressures relative to pore pressure are also maintained, thereby simulating the formations at depth. Core samples from formations may also be investigated using the apparatus and method hereof, for carbon dioxide sequestration potential, as another example.

Abstract: An apparatus and method for simulating production conditions in hydrocarbon-bearing reservoirs, as an example, by flooding of core samples from such reservoirs, are described. Full recirculation flow measurements permit several fluids (for example, crude oil, brine, and gas) to be simultaneously injected into core samples having varying dimensions. Accurate and stable back pressures are maintained at total flow rates of as high as 200 cc/min., for a large range of fluid viscosities. Accurate and stable net overburden pressures relative to pore pressure are also maintained, thereby simulating the formations at depth. Core samples from formations may also be investigated using the apparatus and method hereof, for carbon dioxide sequestration potential, as another example.