Flow Of A Disperse Emulsion Of Crude Oil In Water In Porous Media

1969 ◽  
Author(s):  
John C. Cartmill ◽  
Parke A. Dickey
Keyword(s):  
Porous Media ◽  
Crude Oil ◽  
Oil In Water

Flow of Oil-in-Water Emulsions Through Tubes and Porous Media

1979 ◽  
Vol 19 (06) ◽  
pp. 369-377 ◽  
Author(s):  
D.A. Alvarado ◽  
S.S. Marsden
Keyword(s):  
Porous Media ◽  
Crude Oil ◽  
Capillary Tube ◽  
Flow Behavior ◽  
Oil Field ◽  
Newtonian Fluids ◽  
Capillary Tubes ◽  
The Past ◽  
Oil In Water ◽  
Physical Laws

Abstract The flow of oil-in-water macroemulsions through both porous media and capillary tubes has been studied experimentally and described mathematically. Macroemulsions are those emulsions with most of their droplet diameters greater than I AM, which is the same order of magnitude as the pore constrictions. The emulsions were pumped with a positive displacement pump through several porous media and capillary tubes connected in series. The rheological behavior of macroemulsions with oil concentrations ranging from 10 to 70 vol% was obtained using capillary tube data. Emulsions with oil concentrations less than 50% behaved like Newtonian fluids, white those with concentrations greater than 50% behaved like pseudoplastic fluids. Viscoelastic effects were not observed for these fluids. A correlation, which uses both capillary and core flow data, was developed for describing the flow of non-Newtonian macroemulsions through porous media. This led to a general equation that reduced to Darcy's law for Newtonian fluids. The average relative error found when applying the method of correlation was +/- 4 %. Introduction The subject of emulsions is a broad field that includes many instances of application in industry. We are interested mainly in one specific area of application here - the oil industry. The study of emulsions has received considerable attention in petroleum research laboratories during the past 15 petroleum research laboratories during the past 15 years. The development of new methods of secondary recovery and the potential application of crude oil transportation through pipelines as stable emulsions have increased the number of research programs dealing with emulsions. programs dealing with emulsions. Macroemulsions, or ordinary emulsions, are dispersions of one liquid within another liquid. third component in an emulsion is the emulsifying agent or emulsifier, which has two principal functions:to decrease the interfacial tension between the liquids, thereby enabling easier formation of the greatly extended interface, andto stabilize the dispersed phase against coalescence once it is formed. With water or brine as one of the liquids, two types of emulsions are possible - oil-in-water (O/W) and water-in-oil (W/O) emulsions. Note that most of worlds's crude oil is produced in emulsion form. These emulsions are generally water-in-crude oil emulsions, which are more viscous than either of their constituents. Since we are interested only in maximum economical oil production, it is a common practice to separate emulsions production, it is a common practice to separate emulsions into their components, thereby obtaining reduced viscosity. This is accomplished in the oil field by using chemical and heat treatments. In contrast to W/O emulsions, O/W emulsions have lower viscosities than their oil constituent. This was considered by some investigators during the development of systems for producing and transporting crude oil as O/W emulsions. During the last decade or so, a number of new secondary oil recovery processes have been developed. These methods include the use of high-viscosity emulsions to displace oil, the use of emulsion slugs between the displacing fluid (water) and the displaced fluid (Oil), and controlled viscosity microemulsions. We see that, for an engineer to describe properly the flow behavior of emulsions in both pipelines and reservoirs, he must know the properties of emulsions and the physical laws properties of emulsions and the physical laws controlling their flow through tubes and porous media. The purpose of this research was to study the flow of O/W macroemulsions through both porous media and capillary tubes. The rheological characteristics of emulsions were analyzed by using capillary viscometers. SPEJ P. 369

Dynamic flow response of crude oil-in-water emulsion during flow through porous media

Fuel ◽  
2014 ◽  
Vol 135 ◽  
pp. 38-45 ◽  
Author(s):  
Mehrnoosh Moradi ◽  
Mahdi Kazempour ◽  
Joshua T. French ◽  
Vladimir Alvarado
Keyword(s):  
Porous Media ◽  
Crude Oil ◽  
Flow Through Porous Media ◽  
Dynamic Flow ◽  
Water Emulsion ◽  
Flow Response ◽  
Oil In Water ◽  
Flow Through ◽  
Oil In Water Emulsion

scholarly journals CO2 Convective Dissolution in Oil-Saturated Unconsolidated Porous Media at Reservoir Conditions

Energies ◽  
2021 ◽  
Vol 14 (1) ◽  
pp. 233
Author(s):  
Widuramina Amarasinghe ◽  
Ingebret Fjelde ◽  
Nils Giske ◽  
Ying Guo
Keyword(s):  
Porous Media ◽  
Crude Oil ◽  
Water Solution ◽  
Co2 Storage ◽  
Bromothymol Blue ◽  
Power Relationship ◽  
Dimensionless Time ◽  
3 Dimensional ◽  
Reservoir Conditions ◽  
Unconsolidated Porous Media

During CO2 storage, CO2 plume mixes with the water and oil present at the reservoir, initiated by diffusion followed by a density gradient that leads to a convective flow. Studies are available where CO2 convective mixing have been studied in water phase but limited in oil phase. This study was conducted to reach this gap, and experiments were conducted in a vertically packed 3-dimensional column with oil-saturated unconsolidated porous media at 100 bar and 50 °C (representative of reservoir pressure and temperature conditions). N-Decane and crude oil were used as oils, and glass beads as porous media. A bromothymol blue water solution-filled sapphire cell connected at the bottom of the column was used to monitor the CO2 breakthrough. With the increase of the Rayleigh number, the CO2 transport rate in n-decane was found to increase as a function of a second order polynomial. Ra number vs. dimensionless time τ had a power relationship in the form of Ra = c×τ−n. The overall pressure decay was faster in n-decane compared to crude oil for similar permeability (4 D), and the crude oil had a breakthrough time three times slower than in n-decane. The results were compared with similar experiments that have been carried out using water.

Study on the pressure drop of crude oil-water with surfactant flow in porous media

2021 ◽  
pp. 1-7
Author(s):  
Huijun Zhao ◽  
Xiang Ding ◽  
Pengfei Yu ◽  
Yun Lei ◽  
Xiaofei Lv ◽  
...  
Keyword(s):  
Porous Media ◽  
Pressure Drop ◽  
Crude Oil ◽  
Flow In Porous Media ◽  
Oil Water

Surfactant Retention in Berea Sandstone- Effects of Phase Behavior and Temperature

1982 ◽  
Vol 22 (06) ◽  
pp. 962-970 ◽  
Author(s):  
J. Novosad
Keyword(s):  
Porous Media ◽  
Crude Oil ◽  
Phase Behavior ◽  
Oil Recovery ◽  
Liquid Interface ◽  
Divalent Ions ◽  
Surfactant Precipitation ◽  
Wide Range ◽  
Solid Liquid Interface ◽  
Solid Liquid

Novosad, J., SPE, Petroleum Recovery Inst. Abstract Experimental procedures designed to differentiate between surfactant retained in porous media because of adsorption and surfactant retained because Of unfavorable phase behavior are developed and tested with three types of surfactants. Several series of experiments with systematic changes in one variable such as surfactant/cosurfactant ratio, slug size, or temperature are performed, and overall surfactant retention then is interpreted in terms of adsorption and losses caused by unfavorable phase behavior. Introduction Adsorption of surfactants considered for enhanced oil recovery (EOR) applications has been studied extensively in the last few years since it has been shown that it is possible to develop surfactant systems that displace oil from porous media almost completely when used in large quantities. Effective oil recovery by surfactants is not a question of principle but rather a question of economics. Since surfactants are more expensive than crude oil, development of a practical EOR technology depends on how much surfactant can be sacrificed economically while recovering additional crude oil from a reservoir.It was recognized earlier that adsorption may be only one of a number of factors that contribute to total surfactant retention. Other mechanisms may include surfactant entrapment in an immobile oil phase surfactant precipitation by divalent ions, surfactant precipitation caused by a separation of the cosurfactant from the surfactant, and surfactant precipitation resulting from chromatographic separation of different surfactant specks. The principal objective of this work is to evaluate the experimental techniques that can be used for measuring surfactant adsorption and to study experimentally two mechanisms responsible for surfactant retention. Specifically, we try to differentiate between the adsorption of surfactants at the solid/liquid interface and the retention of the surfactants because of trapping in the immobile hydrocarbon phase that remains within the core following a surfactant flood. Measurement of Adsorption at the Solid/Liquid Interface Previous adsorption measurements of surfactants considered for EOR produced adsorption isotherms of unusual shapes and unexpected features. Primarily, an adsorption maximum was observed when total surfactant retention was plotted against the concentration of injected surfactant. Numerous explanations have been offered for these peaks, such as a formation of mixed micelles, the effects of structure-forming and structurebreaking cations, and the precipitation and consequent redissolution of divalent ions. It is difficult to assess which of these effects is responsible for the peaks in a particular situation and their relative importance. However, in view of the number of physicochemical processes taking place simultaneously and the large number of components present in most systems, it seems that we should not expect smooth monotonically increasing isotherms patterned after adsorption isothemes obtained with one pure component and a solvent. Also, it should be realized that most experimental procedures do not yield an amount of surfactant adsorbed but rather a measure of the surface excess.An adsorption isotherm, expressed in terms of the surface excess as a function of an equilibrium surfactant concentration, by definition must contain a maximum if the data are measured over a sufficiently wide range of concentrations. SPEJ P. 962^

Pore-Scale Transport Mechanisms and Macroscopic Displacement Effects of In-Situ Oil-in-Water Emulsions in Porous Media

2018 ◽  
Vol 140 (10) ◽  
Author(s):  
Chuan Lu ◽  
Wei Zhao ◽  
Yongge Liu ◽  
Xiaohu Dong
Keyword(s):  
Porous Media ◽  
Oil Recovery ◽  
Heavy Oil ◽  
Mobility Control ◽  
Pore Scale ◽  
Sweep Efficiency ◽  
Emulsion Droplets ◽  
Oil In Water ◽  
Retention Volumes

Oil-in-water (O/W) emulsions are expected to be formed in the process of surfactant flooding for heavy oil reservoirs in order to strengthen the fluidity of heavy oil and enhance oil recovery. However, there is still a lack of detailed understanding of mechanisms and effects involved in the flow of O/W emulsions in porous media. In this study, a pore-scale transparent model packed with glass beads was first used to investigate the transport and retention mechanisms of in situ generated O/W emulsions. Then, a double-sandpack model with different permeabilities was used to further study the effect of in situ formed O/W emulsions on the improvement of sweep efficiency and oil recovery. The pore-scale visualization experiment presented an in situ emulsification process. The in situ formed O/W emulsions could absorb to the surface of pore-throats, and plug pore-throats through mechanisms of capture-plugging (by a single emulsion droplet) and superposition-plugging or annulus-plugging (by multiple emulsion droplets). The double-sandpack experiments proved that the in situ formed O/W emulsion droplets were beneficial for the mobility control in the high permeability sandpack and the oil recovery enhancement in the low permeability sandpack. The size distribution of the produced emulsions proved that larger pressures were capable to displace larger O/W emulsion droplets out of the pore-throat and reduce their retention volumes.

The effect of non-ionic surfactant on the internal corrosion for X52 steel in extra-heavy crude oil-in-water emulsions

2018 ◽  
Vol 65 (3) ◽  
pp. 234-248 ◽  
Author(s):  
L.M. Quej-Ake ◽  
A. Contreras ◽  
Jorge Aburto
Keyword(s):  
Crude Oil ◽  
Steel Surface ◽  
Corrosion Process ◽  
Ionic Surfactant ◽  
Heavy Crude Oil ◽  
Content Type ◽  
Oil In Water ◽  
X52 Steel ◽  
Emulsion Systems ◽  
Heavy Crude

Purpose The purpose of this research is to study different extra-heavy crude oil-in-water emulsions that can be found in practice for corrosion process of X52 steel adding 60 mg.L-1 of non-ionic surfactant and a corrosion inhibitor (CI). Electrochemical impedance spectroscopy and Tafel plots are carried out. Thus, Bode-modulus and Bode-phase angle plots are discussed. Adsorption isotherms obtained from corrosion rate (CR) values are taken into account. Design/methodology/approach Two-electrode arrangement is used to characterize the pseudo-capacitance values for X52 steel exposed to water and crude oil phases, mainly. Electrochemical evaluations for X52 steel exposed to extra-heavy crude oil-in-water emulsions are recorded in a conventional three-electrode cell to study the corrosion process as was documented in detail by Quej-Ake et al. (2015). Therefore, all electrodes are placed as close as possible to eliminate the iR-drop. Findings Pseudo-capacitance analysis shows that X52 steel immersed in oilfield produced water was more susceptible to corrosion than that immersed in ocean water solution and extra-heavy crude oil phase. After being analyzed, the X52 steel surface coverage and adsorption process for surfactant and CI could be concluded that surfactant could protect the metal surface. In a coalescence extra-heavy crude oil-in-water emulsion, the water medium generated a new solution that was more corrosive than the original water phase. Wash crude oil process was provoked in emulsion systems to sweep up the salts, mainly. Thus, corrosive species that can be recovered inside extra-heavy crude oil may appear, and in turn a new more corrosive solution could be obtained. Taking into account the straight line obtained in Bode-modulus plot for X52 exposed to extra-heavy crude oil, it is possible to point out that the negative value of the slope or R2 can be related to a coefficient (Jorcin et al., 2006). It is important to mention that electrochemical responses for X52 steel exposed to extra-heavy crude oil-in-water under coalescence emulsions revealed that corrosion and diffusion processes exist. Therefore, a possible good inhibitor is surfactant in emulsion systems. Originality/value CR and anodic and cathodic slopes suggest that the surfactant acted as mixed CI. Of these, susceptible anodic (MnS and perlite or cementite) and cathodic (ferrite) sites on steel surface could be affected, due to which physicochemical adsorption could happen by using electrochemical parameters analysis. Thus, no stable emulsions should be taken into account for extra-heavy crude oil transportation, because corrosion problems in atmospheric distillation process of the crude oil due to stable emulsion cannot be easily separated. In this manner, coalescent emulsions are more adequate for transporting extra-heavy crude oil because low energy to separate the water media is required.

Sign in / Sign up

Export Citation Format

Share Document