A numerical study of the effects of temperature and injection velocity on oil-water relative permeability for enhanced oil recovery

Iyi, Draco; Balogun, Yakubu; Oyeneyin, Babs; Faisal, Nadimul Haque

doi:10.1016/j.ijheatmasstransfer.2022.122863

Cited by 12 publications

(3 citation statements)

References 26 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…In conclusion, employing nanofluids instead of water considerably increased the EOR process' performance. Literature has also reported similar results [ [42] , [43] , [44] ]. Geometry is used in nanoflooding for oil recovery by considering the size and form of nanoparticles, understanding the geometry of porous media, optimizing injection patterns and well placement, and analyzing capillary and interfacial forces.…”

Section: Resultssupporting

confidence: 73%

A numerical investigation of mathematical modelling in 3D hexagonal porous prism on oil recovery using nanoflooding

Zafar,

Sakidin,

Sheremet

et al. 2023

Heliyon

View full text Add to dashboard Cite

Section: Resultssupporting

confidence: 73%

A numerical investigation of mathematical modelling in 3D hexagonal porous prism on oil recovery using nanoflooding

Zafar,

Sakidin,

Sheremet

et al. 2023

Heliyon

View full text Add to dashboard Cite

“…As the flow rate increased, the residual brine saturation decreased, and the endpoint CO 2 relative permeability increased. Lyi et al [224] used the ANSYS-CFD technique to establish a numerical model for hot water injection in oil-bearing sandstone cores. It was found that the permeability (relative) of the oil flow curve was strongly influenced by the flow rate, whereas water had little or no effect on the relative permeability.…”

Section: Effects Of Interphase Propertiesmentioning

confidence: 99%

Thermodynamic Properties of a Gas–Liquid–Solid System during the CO2 Geological Storage and Utilization Process: A Review

Mutailipu,

Xue,

et al. 2023

Energies

View full text Add to dashboard Cite

Emission reduction in the main greenhouse gas, CO2, can be achieved efficiently via CO2 geological storage and utilization (CCUS) methods such as the CO2 enhanced oil/water/gas recovery technique, which is considered to be an important strategic technology for the low-carbon development of China’s coal-based energy system. During the CCUS, the thermodynamic properties of the CO2–water–rock system, such as the interfacial tension (IFT) and wettability of the caprock, determine the injectability, sealing capacity, and safety of this scheme. Thus, researchers have been conducting laboratory experiments and modeling work on the interfacial tension between CO2 and the water/brine, wettability of caprocks, the solubility of gas–liquid binary systems, and the pH of CO2-saturated brine under reservoir temperature and pressure conditions. In this study, the literature related to the thermodynamic properties of the CO2–water–rock system is reviewed, and the main findings of previous studies are listed and discussed thoroughly. It is concluded that limited research is available on the pH of gas-saturated aqueous solutions under CO2 saline aquifer storage conditions, and less emphasis has been given to the wettability of the CO2–water/brine–rock system. Thus, further laboratory and modeling research on the wettability alternations of caprock in terms of molecular dynamics is required to simulate this phenomenon at the molecular level. Moreover, simplified IFT and solubility prediction models with thermodynamic significance and high integrity need to be developed. Furthermore, interaction mechanisms coupling with multi-factors associated with the gas–liquid–solid interface properties and the dissolution and acidification process need to be explored in future work.

show abstract

“…It was observed that when the temperature increased, the oil saturation decreased while the water saturation increased. At temperatures below 100°C, it has been shown that the permeability becomes more sensitive [21]. It represented a model that considers the transfer of the oil phase from formation waters to rocks due to trapping effects.…”

Section: Introductionmentioning

confidence: 99%

Studying the Transmission Behavior of Two-Phase Flow Oil-Water Mixing Using a Laboratory Multiple Porous Media Model

Thijeel,

Muhsun

2023

IOP Conf. Ser.: Earth Environ. Sci.

View full text Add to dashboard Cite

The formation and flow of emulsions in porous media are common to all technologies used to extract or process oil. In most cases, oil and water emulsions are formed in a porous medium due to oil spills near watery areas or soils containing water. This emulsion leads to a reaction between oil and water, which finds its way to the porous medium. The detailed flow mechanisms of emulsions through porous media are not well understood. In this study, the soil’s oil percentage variation was studied when sand was introduced or an emulsion, i.e., mixed with water, and two porous media, different in composition and physical properties, were used to find out their effect on oil transmission. The percentage of oil and water was calculated at several points at different distances and times. It was noted that the results differed in both mediums due to the difference in permeability, porosity, arrangement of soil particles, compaction process, and other physical properties. Liquids’ viscosity, density, and chemical composition clearly and significantly affect the results. The time for the oil to reach the last point in the pipe differed for both soils. If the time period in the experiment of pumping oil only in sandy soil took 6 hours and the washing process took 3 hours. In organic soil, the time period for the pollutant pumping stage took about 7 hours and the washing stage about 4 hours because the oil is transmitted in sandy soil is faster, but in the experiment of pumping oil and water together, the time period in the process of pumping oil and water together in sandy soil took 4 hours and the washing process 3 hours In organic soil, the period of pumping oil and water together took 5 hours, and the washing period 3 hours, because the percentage of oil was less than in the experiment of pumping oil only. In the soil, that is, if the period of pumping the pollutant increased for more than 15 hours, the oil may reach a distance of more than 4 meters in the soil. As for the washing process, when the oil is mixed with water, it gives better results when washing it than if the oil enters alone into the soil because the proportions of oil when it enters the soil together with the water, it is little and does not rise much, so it is easy to wash.

show abstract

A numerical study of the effects of temperature and injection velocity on oil-water relative permeability for enhanced oil recovery

Cited by 12 publications

References 26 publications

A numerical investigation of mathematical modelling in 3D hexagonal porous prism on oil recovery using nanoflooding

A numerical investigation of mathematical modelling in 3D hexagonal porous prism on oil recovery using nanoflooding

Thermodynamic Properties of a Gas–Liquid–Solid System during the CO2 Geological Storage and Utilization Process: A Review

Studying the Transmission Behavior of Two-Phase Flow Oil-Water Mixing Using a Laboratory Multiple Porous Media Model

Contact Info

Product

Resources

About