University of Wyoming

Mohammad Piri

Soheil Saraji

Lamia Goual

Rami Alloush

Vahideh Mirchi

Morteza Akbarabadi

Magda Ibrahim Youssif Mohamed Soliman

Alvinda Sri Hanamertani

Elizabeth Barsotti

Van Si Le

Evan W Lowry

Tianzhu Qin

Shixun Bai

Keerti Vardhan Sharma

Jan Kubelka

Gina Javanbakht

Ewan W Lowry

Embodiments relate to methods and materials for foam production in enhanced oil recovery operations and to foaming agents, gas mobility control agents for use in porous media, compositions comprising such agents, methods for using such agents, methods for generating foams, and systems for enhanced oil recovery. In an embodiment, a method for recovery of oil from a porous rock formation includes contacting a foaming fluid and a surfactant solution with the porous rock formation, and generating a foam comprising the foaming fluid and the surfactant solution. The method further includes mobilizing oil from the porous rock formation by contacting the porous rock formation with the foam, and collecting at least a portion of the mobilized oil.

Foaming agents, gas mobility control agents, methods, and systems for enhanced oil recovery

Embodiments of the present disclosure generally relate to methods and apparatus for enhanced oil recovery. In an embodiment, a method of enhanced oil recovery from a reservoir is provided. The method includes determining a three-dimensional molecular association between simulated oil and a simulated surface using molecular dynamics, and selecting a reservoir additive from a plurality of additives. The method further includes introducing the reservoir additive to the reservoir, and recovering oil from the reservoir using the reservoir additive. Methods of testing a candidate chemical or candidate formulation for use in enhanced oil recovery, and methods of determining an effect of a candidate chemical or formulation of candidate chemicals for use in enhanced oil recovery are also described. Oil extraction apparatus are also provided.

Methods and apparatus for enhanced oil recovery

Embodiments of the present disclosure generally relate to apparatus, systems, and methods for characterizing fluid-solid systems. In an embodiment, a method includes placing a porous rock sample in a core holder, contacting the porous rock sample with a fluid to create a fluid-solid system inside the core holder, automatically adjusting a temperature and/or pressure of the fluid-solid system to a preselected value via a processor and at least one automated valve, monitoring the fluid-solid system for equilibrium, recording a value for temperature, pressure, and/or mass of the fluid-solid system, performing an action based on the recorded data, and repeating the adjusting, monitoring, recording, and performing operations to produce a thermodynamic data characteristic of the fluid-solid system. In one example, the performing operation includes analyzing a pressure signal for stationarity by performing an Augmented Dickey-Fuller (ADF) test and/or a Kwiatkowski-Phillips-Schmidt-Shin (KPSS) test.

Automated apparatus for characterization of fluid-solid systems

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.

Microemulsions and uses thereof to displace oil in heterogeneous porous media

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.

Methods for determining an optimal surfactant structure for oil recovery

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.

Nanocondensation apparatus

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.

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.

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Laramie, WY, United States of America

Mohammad Piri