Efficiency of application of water-gas mixtures used to increase oil recovery and rearrange fluid flow

The fluid flow in fractured porous media plays a significant role in the characteristic/assessment of deep underground reservoirs such as CO2 sequestration [1–3], enhanced oil recovery [4,5] and geothermal energy development [...]

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High pressure performance of thin Pd–23%Ag/stainless steel composite membranes in water gas shift gas mixtures; influence of dilution, mass transfer and surface effects on the hydrogen flux

Journal of Membrane Science ◽

10.1016/j.memsci.2007.08.056 ◽

2008 ◽

Vol 316 (1-2) ◽

pp. 119-127 ◽

Cited By ~ 173

Author(s):

T.A. Peters ◽

M. Stange ◽

H. Klette ◽

R. Bredesen

Keyword(s):

Mass Transfer ◽

High Pressure ◽

Stainless Steel ◽

Composite Membranes ◽

Surface Effects ◽

Gas Mixtures ◽

Water Gas Shift ◽

Hydrogen Flux ◽

Steel Composite ◽

Water Gas

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Penerapan Dinamika Fluida dalam Perhitungan Kecepatan Aliran dan Perolehan Minyak di Reservoir

ComTech Computer Mathematics and Engineering Applications ◽

10.21512/comtech.v5i2.2232 ◽

2014 ◽

Vol 5 (2) ◽

pp. 707

Author(s):

Dwi Listriana Kusumastuti

Keyword(s):

Fluid Dynamics ◽

Fluid Flow ◽

Flow Velocity ◽

Oil Recovery ◽

Control Volume ◽

Petroleum Industry ◽

Reservoir Rock ◽

Curved Pipe ◽

Fluid Flow Velocity ◽

Control Volumes

Water, oil and gas inside the earth are stored in the pores of the reservoir rock. In the world of petroleum industry, calculation of volume of the oil that can be recovered from the reservoir is something important to do. This calculation involves the calculation of the velocity of fluid flow by utilizing the principles and formulas provided by the Fluid Dynamics. The formula is usually applied to the fluid flow passing through a well defined control volume, for example: cylinder, curved pipe, straight pipes with different diameters at the input and output, and so forth. However, because of reservoir rock, as the fluid flow medium, has a wide variety of possible forms of the control volumes, hence, calculation of the velocity of the fluid flow is becoming difficult as it would involve calculations of fluid flow velocity for each control volume. This difficulties is mainly caused by the fact that these control volumes, that existed in the rock, cannot be well defined. This paper will describe a method for calculating this fluid flow velocity of the control volume, which consists of a combination of laboratory measurements and the use of some theories in the Fluid Dynamics. This method has been proofed can be used for calculating fluid flow velocity as well as oil recovery in reservoir rocks, with fairly good accuration.

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Modelling the influence of interaction between injection and formation brine salinities on in-situ microbial enhanced oil recovery processes by coupling of multiple-ion exchange transport model with multiphase fluid flow and multi-species reactive transport models

Journal of Petroleum Science and Engineering ◽

10.1016/j.petrol.2018.01.004 ◽

2018 ◽

Vol 163 ◽

pp. 435-452 ◽

Cited By ~ 6

Author(s):

P. Sivasankar ◽

G. Suresh Kumar

Keyword(s):

Fluid Flow ◽

Oil Recovery ◽

Reactive Transport ◽

Transport Model ◽

Microbial Enhanced Oil Recovery ◽

Transport Models ◽

Recovery Processes ◽

Multiphase Fluid Flow ◽

Multiphase Fluid

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Experimental Investigation of Chemical Flooding Using Nanoparticles and Polymer on Displacement of Crude Oil for Enhanced Oil Recovery

International Journal of Chemical Engineering ◽

10.1155/2020/1806282 ◽

2020 ◽

Vol 2020 ◽

pp. 1-10

Author(s):

Imran Akbar ◽

Hongtao Zhou ◽

Wei Liu ◽

Muhammad Usman Tahir ◽

Asadullah Memon ◽

...

Keyword(s):

Fluid Flow ◽

Enhanced Oil Recovery ◽

Oil Recovery ◽

Petroleum Industry ◽

Chemical Flooding ◽

Polymer Gel ◽

Core Flooding ◽

High Concentration ◽

Remaining Oil ◽

Water Cut

In the petroleum industry, the researchers have developed a new technique called enhanced oil recovery to recover the remaining oil in reservoirs. Some reservoirs are very complex and require advanced enhanced oil recovery (EOR) techniques containing new materials and additives in order to produce maximum oil in economic and environmental friendly manners. In this work, the effects of nanosuspensions (KY-200) and polymer gel HPAM (854) on oil recovery and water cut were studied in the view of EOR techniques and their results were compared. The mechanism of nanosuspensions transportation through the sand pack was also discussed. The adopted methodology involved the preparation of gel, viscosity test, and core flooding experiments. The optimum concentration of nanosuspensions after viscosity tests was used for displacement experiments and 3 wt % concentration of nanosuspensions amplified the oil recovery. In addition, high concentration leads to more agglomeration; thus, high core plugging takes place and diverts the fluid flow towards unswept zones to push more oil to produce and decrease the water cut. Experimental results indicate that nanosuspensions have the ability to plug the thief zones of water channeling and can divert the fluid flow towards unswept zones to recover the remaining oil from the reservoir excessively rather than the normal polymer gel flooding. The injection pressure was observed higher during nanosuspension injection than polymer gel injection. The oil recovery was achieved by about 41.04% from nanosuspensions, that is, 14.09% higher than polymer gel. Further investigations are required in the field of nanoparticles applications in enhanced oil recovery to meet the world's energy demands.

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Laboratory Researches of the Heavy Oil Displacement from the Russkoye Field's Core Models at the SWAG Injection and Development of Technological Schemes of Pump-Ejecting Systems for the Water-Gas Mixtures Delivering

10.2118/157819-ms ◽

2012 ◽

Cited By ~ 1

Author(s):

Alexander Nikolaevich Drozdov ◽

Nikolay Alexandrovich Drozdov

Keyword(s):

Heavy Oil ◽

Gas Mixtures ◽

Oil Displacement ◽

Water Gas

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Transport Modelling of Multi-Phase Fluid Flow in Porous Media for Enhanced Oil Recovery

Defect and Diffusion Forum ◽

10.4028/www.scientific.net/ddf.400.38 ◽

2020 ◽

Vol 400 ◽

pp. 38-44

Author(s):

Hassan Soleimani ◽

Hassan Ali ◽

Noorhana Yahya ◽

Beh Hoe Guan ◽

Maziyar Sabet ◽

...

Keyword(s):

Porous Media ◽

Fluid Flow ◽

Capillary Pressure ◽

Oil Recovery ◽

Constitutive Relations ◽

Mobility Control ◽

Flow In Porous Media ◽

Wettability Alteration ◽

Adsorption Effect ◽

Phase Fluid

This article studies the combined effect of spatial heterogeneity and capillary pressure on the saturation of two fluids during the injection of immiscible nanoparticles. Various literature review exhibited that the nanoparticles are helpful in enhancing the oil recovery by varying several mechanisms, like wettability alteration, interfacial tension, disjoining pressure and mobility control. Multiphase modelling of fluids in porous media comprise balance equation formulation, and constitutive relations for both interphase mass transfer and pressure saturation curves. A classical equation of advection-dispersion is normally used to simulate the fluid flow in porous media, but this equation is unable to simulate nanoparticles flow due to the adsorption effect which happens. Several modifications on computational fluid dynamics (CFD) have been made to increase the number of unknown variables. The simulation results indicated the successful transportation of nanoparticles in two phase fluid flow in porous medium which helps in decreasing the wettability of rocks and hence increasing the oil recovery. The saturation, permeability and capillary pressure curves show that the wettability of the rocks increases with the increasing saturation of wetting phase (brine).

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