Chemical enhanced oil recovery in unconventional reservoirs

Dastjerdi, Ali Mirzaalian; Ashoorian, Sefatallah

doi:10.1016/b978-0-12-821931-7.00004-3

Cited by 3 publications

(4 citation statements)

References 55 publications

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“…The amount of gas diffusing in the liquid phase is calculated from the change in pressure or volume of the gas phase using the equation of state (EOS) of real gases (Astanina & Sheremet, 2023;Upreti & Mehrotra, 2000). Grogan et al proposed a glass capillary tube to measure the CO 2 diffusion coefficient in light oils under high pressure (Mirzaalian et al, 2023). A layer of CO 2 gas is created in the middle of the capillary tube filled with an oil sample.…”

Section: Experimental Estimation Of Carbon Dioxide Diffusion In Fluid...mentioning

confidence: 99%

“…The position of the CO 2 and oil mixture in the tube is detected as a function of time to calculate the diffusion coefficient using a numerical model. Although this method can be used to measure the CO 2 diffusion coefficient in the liquid phase, it is difficult to apply it to saturated porous media, as the researchers pointed out, because some additional operations are required in the experiment to show the effect of convection on the measurement results (Mirzaalian et al, 2023).…”

Section: Experimental Estimation Of Carbon Dioxide Diffusion In Fluid...mentioning

confidence: 99%

“…The results of CO 2 diffusion coefficient determination obtained by the conventional PVT method may contain some errors. To overcome some drawbacks, the author Mirzaalian et al (2023) presented a new method for measuring the effective CO 2 diffusion coefficient under reservoir conditions in oil-saturated porous media. A porous medium with two closed ends is considered as a physical model of the radial diffusion process.…”

Section: Experimental Estimation Of Carbon Dioxide Diffusion In Fluid...mentioning

confidence: 99%

“…A mathematical model is proposed along with measurements as well as numerical solutions to describe these processes. The effective diffusion coefficient is determined by comparing the experimental pressure drop curve with the corresponding mathematical model (Mirzaalian et al, 2023). The method can be easily applied in laboratories capable of handling high-pressure fluids; thus, this study can be presented as a tool for research on CO 2 diffusion in oil-saturated porous medium.…”

Section: Experimental Estimation Of Carbon Dioxide Diffusion In Fluid...mentioning

confidence: 99%

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Modelling of Internal Transformations of Gas Phase in Porous Media

Panahov

2024

AMMA

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The paper presents the research of temperature change in the investigated medium during dynamic expansion of gas (CO2) generated in reservoir conditions, diffusion of carbon dioxide into the displacing fluid and their influence on the displacement process. In-situ gas generation can provide a way to control the nonequilibrium fractal state at the interface under displacement in a porous medium. The change from fractal growth to non-fractal growth can be characterised as a function of density and viscosity ratios. This effect is shown in the increase of hydrocarbon displacement coefficient due to the equalisation of densities of displacing and displaced agents as a consequence of the increase in gas saturation of the fluid.

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Section: Experimental Estimation Of Carbon Dioxide Diffusion In Fluid...mentioning

confidence: 99%

Section: Experimental Estimation Of Carbon Dioxide Diffusion In Fluid...mentioning

confidence: 99%

Section: Experimental Estimation Of Carbon Dioxide Diffusion In Fluid...mentioning

confidence: 99%

Section: Experimental Estimation Of Carbon Dioxide Diffusion In Fluid...mentioning

confidence: 99%

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Modelling of Internal Transformations of Gas Phase in Porous Media

Panahov

2024

AMMA

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Steam-assisted gravity drainage

Hayatdavoudi¹,

Ashoorian²,

Hosseinpour³

2023

Thermal Methods

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A Review of the Seepage Mechanisms of Heavy Oil Emulsions during Chemical Flooding

Wang

Taleb

et al. 2022

Energies

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Chemical flooding plays an important role in enhancing oil recovery due to many reasons, including the viscosity-increment effect of polymer, wettability alteration effect of surfactant, and the formation of emulsions, which have been known to effectively increase the swept area and oil displacement efficiency, hence increasing heavy oil recovery. Laboratory tests and pilot trials of alkali–surfactant–polymer (ASP) injection show that the oil recovery of the emulsified system is 5% more than the cases where no emulsions existed. Therefore, it is of great significance to study heavy oil emulsions and its field application for enhanced heavy oil recovery. This paper discusses a thorough overview of the most fundamental ASP flooding mechanisms, along with some examples of laboratory experiments and field trials. In addition, the formation conditions and the interfacial characteristics of heavy oil emulsions are also discussed, mainly ASP flooding, and then the seepage mechanisms of these emulsions are investigated. The relationship between the formation of heavy oil emulsions and the enhanced heavy oil recovery effect by chemical flooding is discussed through core flooding experiments at the reservoir temperature and some field pilots to reach the optimum heavy oil recovery.

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Chemical enhanced oil recovery in unconventional reservoirs

Cited by 3 publications

References 55 publications

Modelling of Internal Transformations of Gas Phase in Porous Media

Modelling of Internal Transformations of Gas Phase in Porous Media

Steam-assisted gravity drainage

A Review of the Seepage Mechanisms of Heavy Oil Emulsions during Chemical Flooding

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