Computational fluid dynamics for ameliorating oil recovery using silicon-based nanofluids and ethanol in oil-wet reservoirs

Ejeh, Chukwugozie Jekwu; Afgan, Imran; AlMansob, Hamzah; Brantson, Eric Thompson; Fekala, Joseph; Odiator, Micah; Stanley, Promise; Anumah, Prosper; Onyekperem, Chigozirim Cyprian; Boah, Evans Annan

doi:10.1016/j.egyr.2020.10.028

Cited by 20 publications

(15 citation statements)

References 51 publications

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“…The term mixed-wet is used to define a formation that has heterogeneous wettability because the formation grains have non-uniform wettability due to different sizes of pores in the formation. The small formation pores are water-wet and the large formation pores are oil-wet (Ejeh et al, 2020).…”

Section: Effect Of Electrical Conductivity On Oil Recoverymentioning

confidence: 99%

Geochemical investigation of electrical conductivity and electrical double layer based wettability alteration during engineered water injection in carbonates

Khurshid

Afgan

2022

Journal of Petroleum Science and Engineering

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Section: Effect Of Electrical Conductivity On Oil Recoverymentioning

confidence: 99%

Geochemical investigation of electrical conductivity and electrical double layer based wettability alteration during engineered water injection in carbonates

Khurshid

Afgan

2022

Journal of Petroleum Science and Engineering

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“…Computational fluid dynamics (CFDs) is a methodology used to examine systems, such as fluid flow and the heat transport system, through computer simulations. When compared to experimental investigations, the CFD technique has the potential to study critical and unique circumstances in a process, reduce response time and research costs, and gain a complete and detailed understanding of the process [ 58 , 59 , 60 , 61 , 62 , 63 , 64 ].…”

Section: Numerical Implementationmentioning

confidence: 99%

Thermophysical Properties of Nanofluid in Two-Phase Fluid Flow through a Porous Rectangular Medium for Enhanced Oil Recovery

et al. 2022

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It is necessary to sustain energy from an external reservoir or employ advanced technologies to enhance oil recovery. A greater volume of oil may be recovered by employing nanofluid flooding. In this study, we investigated oil extraction in a two-phase incompressible fluid in a two-dimensional rectangular porous homogenous area filled with oil and having no capillary pressure. The governing equations that were derived from Darcy’s law and the mass conservation law were solved using the finite element method. Compared to earlier research, a more efficient numerical model is proposed here. The proposed model allows for the cost-effective study of heating-based inlet fluid in enhanced oil recovery (EOR) and uses the empirical correlations of the nanofluid thermophysical properties on the relative permeability equations of the nanofluid and oil, so it is more accurate than other models to determine the higher recovery factor of one nanoparticle compared to other nanoparticles. Next, the effect of nanoparticle volume fraction on flooding was evaluated. EOR via nanofluid flooding processes and the effect of the intake temperatures (300 and 350 K) were also simulated by comparing three nanoparticles: SiO2, Al2O3, and CuO. The results show that adding nanoparticles (<5 v%) to a base fluid enhanced the oil recovery by more than 20%. Increasing the inlet temperature enhanced the oil recovery due to changes in viscosity and density of oil. Increasing the relative permeability of nanofluid while simultaneously reducing the relative permeability of oil due to the presence of nanoparticles was the primary reason for EOR.

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“…Furthermore, at low temperatures, the precipitation of clay/carbonate increases after dissolution because solids are less soluble at low temperatures. Increasing the temperature increases the solubility of calcium carbonate in CO 2 and vice versa [23][24][25][26][27][28][29]. Khurshid et al [30] performed geomechanical analysis of formation deformation due to low-temperature CO 2 injection in depleted oil reservoirs.…”

Section: Effect Of Reservoir Depth and Temperaturementioning

confidence: 99%

Geochemical Investigation of CO2 Injection in Oil and Gas Reservoirs of Middle East to Estimate the Formation Damage and Related Oil Recovery

Khurshid

Afgan

2021

Energies

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The injection performance of carbon dioxide (CO2) for oil recovery depends upon its injection capability and the actual injection rate. The CO2–rock–water interaction could cause severe formation damage by plugging the reservoir pores and reducing the permeability of the reservoir. In this study, a simulator was developed to model the reactivity of injected CO2 at various reservoir depths, under different temperature and pressure conditions. Through the estimation of location and magnitude of the chemical reactions, the simulator is able to predict the effects of change in the reservoir porosity, permeability (due to the formation/dissolution) and transport/deposition of dissoluted particles. The paper also presents the effect of asphaltene on the shift of relative permeability curve and the related oil recovery. Finally, the effect of CO2 injection rate is analyzed to demonstrate the effect of CO2 miscibility on oil recovery from a reservoir. The developed model is validated against the experimental data. The predicted results show that the reservoir temperature, its depth, concentration of asphaltene and rock properties have a significant effect on formation/dissolution and precipitation during CO2 injection. Results showed that deep oil and gas reservoirs are good candidates for CO2 sequestration compared to shallow reservoirs, due to increased temperatures that reduce the dissolution rate and lower the solid precipitation. However, asphaltene deposition reduced the oil recovery by 10%. Moreover, the sensitivity analysis of CO2 injection rates was performed to identify the effect of CO2 injection rate on reduced permeability in deep and high-temperature formations. It was found that increased CO2 injection rates and pressures enable us to reach miscibility pressure. Once this pressure is reached, there are less benefits of injecting CO2 at a higher rate for better pressure maintenance and no further diminution of residual oil.

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Computational fluid dynamics for ameliorating oil recovery using silicon-based nanofluids and ethanol in oil-wet reservoirs

Cited by 20 publications

References 51 publications

Geochemical investigation of electrical conductivity and electrical double layer based wettability alteration during engineered water injection in carbonates

Geochemical investigation of electrical conductivity and electrical double layer based wettability alteration during engineered water injection in carbonates

Thermophysical Properties of Nanofluid in Two-Phase Fluid Flow through a Porous Rectangular Medium for Enhanced Oil Recovery

Geochemical Investigation of CO2 Injection in Oil and Gas Reservoirs of Middle East to Estimate the Formation Damage and Related Oil Recovery

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