Vibratory Mobilization of Two-Phase Liquid Trapped in Capillary

2009 ◽  
Author(s):  
Gang Cheng ◽  
Liming Dai
Keyword(s):  
Porous Media ◽  
Physical Model ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Vibration Frequency ◽  
Experimental Tests ◽  
Two Phase ◽  
Phase Liquid

The newly developed Enhanced Oil Recovery technology implementing vibration and seismic stimulations relies on mobilization of oil trapped in pores of porous media of reservoir. This research indents to investigate the conditions for dynamically mobilizing an oil slug trapped in capillary with controlled vibration. An idealized physical model is established, on which series of experimental tests are performed for determining the conditions. Initiation of the mobilization and the effects of vibration frequency and duration of vibration on the mobilization are analyzed. The results of the research are significant for reveal the mechanism of Enhanced Oil Recovery technology with vibro-seismic stimulation.

scholarly journals Experimental study and numerical modeling for enhancing oil recovery from carbonate reservoirs by nanoparticle flooding

2019 ◽  
Vol 74 ◽  
pp. 5 ◽  
Author(s):  
Mehrdad Sepehri ◽  
Babak Moradi ◽  
Abolghasem Emamzadeh ◽  
Amir H. Mohammadi
Keyword(s):  
Numerical Modeling ◽  
Porous Media ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Recovery Process ◽  
Water Flooding ◽  
Wettability Alteration ◽  
Sensitivity Analyses ◽  
Two Phase ◽  
Fluid Properties

Nowadays, nanotechnology has become a very attractive subject in Enhanced Oil Recovery (EOR) researches. In the current study, a carbonate system has been selected and first the effects of nanoparticles on the rock and fluid properties have been experimentally investigated and then the simulation and numerical modeling of the nanofluid injection for enhanced oil recovery process have been studied. After nanofluid treatment, experimental results have shown wettability alteration. A two-phase flow mathematical model and a numerical simulator considering wettability alteration have been developed. The numerical simulation results show that wettability alteration from oil-wet to water-wet due to presence of nanoparticles can lead to 8–10% increase in recovery factor in comparison with normal water flooding. Different sensitivity analyses and injection scenarios have been considered and assessed. Using numerical modeling, wettability alteration process and formation damage caused by entrainment and entrapment of nanoparticles in porous media have been proved. Finally, the net rate of nanoparticles’ loss in porous media has been investigated.

scholarly journals An Experimental Investigation of Flow Regimes in Imbibition and Drainage Using a Microfluidic Platform

Energies ◽  
2019 ◽  
Vol 12 (7) ◽  
pp. 1390 ◽  
Author(s):  
Feng Guo ◽  
Saman A. Aryana
Keyword(s):  
Porous Media ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Fractal Dimensions ◽  
Immiscible Displacement ◽  
Two Dimensional ◽  
Two Phase ◽  
Dimensional Parameter ◽  
Microfluidic Platform ◽  
Wide Range

Instabilities in immiscible displacement along fluid−fluid displacement fronts in porous media are undesirable in many natural and engineered displacement processes such as geological carbon sequestration and enhanced oil recovery. In this study, a series of immiscible displacement experiments are conducted using a microfluidic platform across a wide range of capillary numbers and viscosity ratios. The microfluidic device features a water-wet porous medium, which is a two-dimensional representation of a Berea sandstone. Data is captured using a high-resolution camera, enabling visualization of the entire domain, while being able to resolve features as small as 10 µm. The study reports a correlation between fractal dimensions of displacement fronts and displacement front patterns in the medium. Results are mapped on a two-dimensional parameter space of log M and log Ca, and stability diagrams proposed in literature for drainage processes are superimposed for comparison. Compared to recent reports in the literature, the results in this work suggest that transition regimes may constitute a slightly larger portion of the overall flow regime diagram. This two-phase immiscible displacement study helps elucidate macroscopic processes at the continuum scale and provides insights relevant to enhanced oil recovery processes and the design of engineered porous media such as exchange columns and membranes.

G125 Visualization of enhanced oil recovery by X-ray CT of two-phase flow in porous media

2012 ◽  
Vol 2012 (0) ◽  
pp. 213-214
Author(s):  
Yudai Suzuki ◽  
Suguru Uemura ◽  
Shohji Tsushima ◽  
Shuichiro Hirai
Keyword(s):  
Porous Media ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Two Phase Flow ◽  
Flow In Porous Media ◽  
Phase Flow ◽  
Two Phase ◽  
X Ray

A MATHEMATICAL MODEL OF MICROBIAL ENHANCED OIL RECOVERY IN POROUS MEDIA

2017 ◽  
Vol 8 (4) ◽  
pp. 263-272
Author(s):  
Jianlong Xiu ◽  
Tianyuan Wang ◽  
Ying Guo ◽  
Qingfeng Cui ◽  
Lixin Huang ◽  
...  
Keyword(s):  
Mathematical Model ◽  
Porous Media ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Microbial Enhanced Oil Recovery

scholarly journals Numerical Simulation of Two-Phase Flows in Heterogeneous Porous Media

2020 ◽  
Vol 21 (2) ◽  
pp. 339
Author(s):  
I. Carneiro ◽  
M. Borges ◽  
S. Malta
Keyword(s):  
Porous Media ◽  
Oil Recovery ◽  
Flow Behavior ◽  
Water Injection ◽  
Heterogeneous Porous Media ◽  
Flow In Porous Media ◽  
High Porosity ◽  
Two Phase ◽  
Recovery Method ◽  
Porosity And Permeability

In this work,we present three-dimensional numerical simulations of water-oil flow in porous media in order to analyze the influence of the heterogeneities in the porosity and permeability fields and, mainly, their relationships upon the phenomenon known in the literature as viscous fingering. For this, typical scenarios of heterogeneous reservoirs submitted to water injection (secondary recovery method) are considered. The results show that the porosity heterogeneities have a markable influence in the flow behavior when the permeability is closely related with porosity, for example, by the Kozeny-Carman (KC) relation.This kind of positive relation leads to a larger oil recovery, as the areas of high permeability(higher flow velocities) are associated with areas of high porosity (higher volume of pores), causing a delay in the breakthrough time. On the other hand, when both fields (porosity and permeability) are heterogeneous but independent of each other the influence of the porosity heterogeneities is smaller and may be negligible.

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