scholarly journals Parametric Study of Polymer-Nanoparticles-Assisted Injectivity Performance for Axisymmetric Two-Phase Flow in EOR Processes

Nanomaterials ◽  
2020 ◽  
Vol 10 (9) ◽  
pp. 1818 ◽  
Author(s):  
Afshin Davarpanah
Keyword(s):  
Oil Recovery ◽  
Polymer Concentration ◽  
Extensive Study ◽  
Recovery Factor ◽  
Sweep Efficiency ◽  
Forward Movement ◽  
Two Phase ◽  
Type Curves ◽  
Wide Range ◽  
Damage Coefficient

Among a wide range of enhanced oil-recovery techniques, polymer flooding has been selected by petroleum industries due to the simplicity and lower cost of operational performances. The reason for this selection is due to the mobility-reduction of the water phase, facilitating the forward-movement of oil. The objective of this comprehensive study is to develop a mathematical model for simultaneous injection of polymer-assisted nanoparticles migration to calculate an oil-recovery factor. Then, a sensitivity analysis is provided to consider the significant influence of formation rheological characteristics as type curves. To achieve this, we concentrated on the driving mathematical equations for the recovery factor and compare each parameter significantly to nurture the differences explicitly. Consequently, due to the results of this extensive study, it is evident that a higher value of mobility ratio, higher polymer concentration and higher formation-damage coefficient leads to a higher recovery factor. The reason for this is that the external filter cake is being made in this period and the subsequent injection of polymer solution administered a higher sweep efficiency and higher recovery factor.

Flooding with Biopolymer from Microbes Derived from Mushroom and Cabbage to Enhance Sweep Efficiency in Enhanced Oil Recovery

2015 ◽  
Vol 1113 ◽  
pp. 492-497 ◽  
Author(s):  
Effah Yahya ◽  
Nur Hashimah Alias ◽  
Tengku Amran Tengku Mohd ◽  
Nurul Aimi Ghazali ◽  
Tajnor Suriya binti Taju Ariffin
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Xanthan Gum ◽  
Shake Flask ◽  
Polymer Concentration ◽  
Edible Mushroom ◽  
Recovery Factor ◽  
Distilled Water ◽  
Sweep Efficiency ◽  
Extraction And Purification

In this study, local isolated Xanthomonas campestries has been used from local cabbage for xanthan gum production via fermentation in shake flask. The product was then recovered with isopropanol and dried. Meanwhile, for extraction and purification of mushroom polysaccharide, we use dead edible mushroom has been used. Polysaccharide mushroom was extracted with NaOH solutions at 100 ͦ C for 24 hrs. Next, polysaccharide was precipitated separately by the addition of ethanol and the resulting polysaccharide extract were dissolved in distilled water. In the present study, different type of biopolymers was used in order to determine the oil recovery with different concentrations. Biopolymers used in this experiment are xanthan gum and mushroom polysaccharide. The properties of both biopolymers were tested for 3000 ppm and 10000 ppm of concentration. The results shown higher oil recovery factor obtained from the mushroom polysaccharide, which is 84.14%. Meanwhile, the highest recovery obtained by xanthan is about 67.44% only. As a conclusion, increasing polymer concentration will increase the oil recovery factor.

scholarly journals Polymer viscosifier systems with potential application for enhanced oil recovery: a review

2021 ◽  
Vol 76 ◽  
pp. 65
Author(s):  
Kelly Lúcia Nazareth Pinho de Aguiar ◽  
Luiz Carlos Magalhães Palermo ◽  
Claudia Regina Elias Mansur
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Polymer Concentration ◽  
High Viscosity ◽  
Water Soluble ◽  
Recovery Factor ◽  
Sweep Efficiency ◽  
Polymeric Fluids ◽  
Excellent Thermal Stability ◽  
Reservoir Conditions

Due to the growing demand for oil and the large number of mature oil fields, Enhanced Oil Recovery (EOR) techniques are increasingly used to increase the oil recovery factor. Among the chemical methods, the use of polymers stands out to increase the viscosity of the injection fluid and harmonize the advance of this fluid in the reservoir to provide greater sweep efficiency. Synthetic polymers based on acrylamide are widely used for EOR, with Partially Hydrolyzed Polyacrylamide (PHPA) being used the most. However, this polymer has low stability under harsh reservoir conditions (High Temperature and Salinity – HTHS). In order to improve the sweep efficiency of polymeric fluids under these conditions, Hydrophobically Modified Associative Polymers (HMAPs) and Thermo-Viscosifying Polymers (TVPs) are being developed. HMAPs contain small amounts of hydrophobic groups in their water-soluble polymeric chains, and above the Critical Association Concentration (CAC), form hydrophobic microdomains that increase the viscosity of the polymer solution. TVPs contain blocks or thermosensitive grafts that self-assemble and form microdomains, substantially increasing the solution’s viscosity. The performance of these systems is strongly influenced by the chemical group inserted in their structures, polymer concentration, salinity and temperature, among other factors. Furthermore, the application of nanoparticles is being investigated to improve the performance of injection polymers applied in EOR. In general, these systems have excellent thermal stability and salinity tolerance along with high viscosity, and therefore increase the oil recovery factor. Thus, these systems can be considered promising agents for enhanced oil recovery applications under harsh conditions, such as high salinity and temperature. Moreover, stands out the use of genetic programming and artificial intelligence to estimate important parameters for reservoir engineering, process improvement, and optimize polymer flooding in enhanced oil recovery.

scholarly journals Surfactant-Polymer Interactions in a Combined Enhanced Oil Recovery Flooding

Energies ◽  
2020 ◽  
Vol 13 (24) ◽  
pp. 6520
Author(s):  
Pablo Druetta ◽  
Francesco Picchioni
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Combined Processes ◽  
Sweep Efficiency ◽  
Two Phase ◽  
Chemical Agents ◽  
Chemical Eor ◽  
Eor Processes ◽  
Adsorption Rates ◽  
Polymer Interaction

The traditional Enhanced Oil Recovery (EOR) processes allow improving the performance of mature oilfields after waterflooding projects. Chemical EOR processes modify different physical properties of the fluids and/or the rock in order to mobilize the oil that remains trapped. Furthermore, combined processes have been proposed to improve the performance, using the properties and synergy of the chemical agents. This paper presents a novel simulator developed for a combined surfactant/polymer flooding in EOR processes. It studies the flow of a two-phase, five-component system (aqueous and organic phases with water, petroleum, surfactant, polymer and salt) in porous media. Polymer and surfactant together affect each other’s interfacial and rheological properties as well as the adsorption rates. This is known in the industry as Surfactant-Polymer Interaction (SPI). The simulations showed that optimum results occur when both chemical agents are injected overlapped, with the polymer in the first place. This procedure decreases the surfactant’s adsorption rates, rendering higher recovery factors. The presence of the salt as fifth component slightly modifies the adsorption rates of both polymer and surfactant, but its influence on the phase behavior allows increasing the surfactant’s sweep efficiency.

Two-Phase Flow (Oil-Water) in Petroleum Reservoir with Irregular Geometry Including Water Injection: Effect of Porosity on the Oil Recovery Factor

2012 ◽  
Vol 326-328 ◽  
pp. 181-186 ◽  
Author(s):  
F. Alves Batista ◽  
B. Gonçalves Coutinho ◽  
Severino Rodrigues de Farias Neto ◽  
Antônio Gilson Barbosa de Lima
Keyword(s):  
Oil Recovery ◽  
Two Phase Flow ◽  
Water Injection ◽  
Recovery Factor ◽  
Phase Flow ◽  
Petroleum Reservoir ◽  
Two Phase ◽  
Fully Implicit ◽  
Irregular Geometry ◽  
Black Oil Model

The aim of this work is to study theoretically the effect of porosity of an oil reservoir with arbitrary geometry on the oil recovery factor. A two-dimensional mathematical modeling (Black-oil model) and numerical solution applied to two-phase flow (water-oil) into the reservoir with irregular geometry including water injection is presented. The conservation equations written in generalized coordinates are solved using the finite volume method, with a fully implicit technique. Results of the pressure and saturation distributions and oil recovery factor over time are presented and evaluated for different values of porosity of the reservoir.

Laboratory Investigations of Factors Influencing Polymer Flood Performance

1975 ◽  
Vol 15 (04) ◽  
pp. 338-346 ◽  
Author(s):  
M.T. Szabo
Keyword(s):  
Oil Recovery ◽  
Polymer Solutions ◽  
Polymer Concentration ◽  
Polymer Flooding ◽  
Mobility Control ◽  
Sweep Efficiency ◽  
Experimental Conditions ◽  
Polymer Injection ◽  
Polymer Flood

Abstract Numerous polymer floods were performed in unconsolidated sand packs using a C14-tagged, cross-linked, partially hydrolyzed ployacrylamide, and the data are compared with brine-flood performance in the same sands. performance in the same sands. The amount of "polymer oil" was linearly proportional to polymer concentration up to a proportional to polymer concentration up to a limiting value. The upper limit of polymer concentration yielding additional polymer oil was considerably higher for a high-permeability sand than for a low-permeability sand. It is shown that a minimum polymer concentration exists, below which no appreciable polymer oil can be produced in high-permeability sands. The effect of polymer slug size on oil recovery is shown for various polymer concentrations, and the results from these tests are used to determine the optimum slug size and polymer concentration for different sands. The effect of salinity was studied by using brine and tap water during polymer floods under similar conditions. Decreased salinity resulted in improved oil recovery at low, polymer concentrations, but it had little effect at higher polymer concentrations. Polymer injection that was started at an advanced stage of brine flood also improved the oil recovery in single-layered sand packs. Experimental data are presented showing the effect of polymer concentration and salinity on polymer-flood performance in stratified reservoir polymer-flood performance in stratified reservoir models. Polymer concentrations in the produced water were measured by analyzing the radioactivity of effluent samples, and the amounts of retained polymer in the stratified models are given for each polymer in the stratified models are given for each experiment. Introduction In the early 1960's, a new technique using dilute polymer solutions to increase oil recovery was polymer solutions to increase oil recovery was introduced in secondary oil-recovery operations. Since then, this new technique has attained wide-spread commercial application. The success and the complexity of this new technology has induced many authors to investigate many aspects of this flooding technique. Laboratory and field studies, along with numerical simulation of polymer flooding, clearly demonstrated that polymer additives increase oil recovery. polymer additives increase oil recovery. Some of the laboratory results have shown that applying polymers in waterflooding reduces the residual oil saturation through an improvement in microscopic sweep efficiency. Other laboratory studies have shown that applying polymer solutions improves the sweep efficiency in polymer solutions improves the sweep efficiency in heterogeneous systems. Numerical simulation of polymer flooding, and a summary of 56 field applications, clearly showed that polymer injection initiated at an early stage of waterflooding is more efficient than when initiated at an advanced stage. Although much useful information has been presented, the experimental conditions were so presented, the experimental conditions were so variable that difficulties arose in correlating the numerical data. So, despite this good data, a systematic laboratory study of the factors influencing the performance of polymer flooding was still lacking in the literature. The purpose of this study was to investigate the effect of polymer concentration, polymer slug size, salinity in the polymer bank, initial water saturation, and permeability on the performance of polymer floods. The role of oil viscosity did not constitute a subject of this investigation. However, some of the data indicated that the applied polymer resulted in added recovery when displacing more viscous oil. The linear polymer-flood tests were coupled with tests in stratified systems, consisting of the same sand materials used in linear flood tests. Thus, it was possible to differentiate between the role of polymer in mobility control behind the flood front in each layer and its role in mobility control in the entire stratified system through improvement in vertical sweep efficiency. A radioactive, C14-tagged hydrolyzed polyacrylamide was used in all oil-recovery tests. polyacrylamide was used in all oil-recovery tests. SPEJ P. 338

scholarly journals Simulation of two-phase flow by injecting water and surfactant into porous media containing oil and investigation of trapped oil areas

2021 ◽  
Vol 11 (3) ◽  
pp. 1353-1362
Author(s):  
Seyed Mousa Sajadi ◽  
Saeid Jamshidi ◽  
Meisam Kamalipoor
Keyword(s):  
Porous Media ◽  
Oil Recovery ◽  
Water Injection ◽  
Sodium Dodecyl ◽  
Recovery Factor ◽  
Wettability Alteration ◽  
Two Phase ◽  
Synthetic Process ◽  
Narrow Channels ◽  
Dynamics Method

AbstractNowadays, as the oil reservoirs reaching their half-life, using enhanced oil recovery methods is more necessary and more common. Simulations are the synthetic process of real systems. In this study, simulation of water and surfactant injection into a porous media containing oil (two-phase) was performed using the computational fluid dynamics method on the image of a real micro-model. Also, the selected anionic surfactant is sodium dodecyl sulfate, which is more effective in sand reservoirs. The effect of using surfactant depends on its concentration. This dependence on concentration in using injection compounds is referred to as critical micelle concentration (CMC). In this study, an injection concentration (inlet boundary) of 1000 ppm was considered as a concentration less than the CMC point (2365 ppm). This range of surfactant concentrations after 4.5 ms increased the porous media recovery factor by 2.21%. Surfactant injection results showed the wettability alteration and IFT finally increases the recovery factor in comparison with water injection. Also, in wide channels, saturation front, and narrow channels, the concentration front has a great effect on the main flowing.

Study of the Effect of Wetting on Viscous Fingering Before and After Breakthrough by Lattice Boltzmann Simulations

2021 ◽  
Author(s):  
Peter Mora ◽  
Gabriele Morra ◽  
Dave Yuen ◽  
Ruben Juanes
Keyword(s):  
Reynolds Number ◽  
Oil Recovery ◽  
Lattice Boltzmann ◽  
Capillary Number ◽  
Viscosity Ratio ◽  
Viscous Fingering ◽  
Wetting Angle ◽  
Recovery Factor ◽  
Transition To Turbulence ◽  
Two Phase

Abstract We present a suite of numerical simulations of two-phase flow through a 2D model of a porous medium using the Rothman-Keller Lattice Boltzmann Method to study the effect of viscous fingering on the recovery factor as a function of viscosity ratio and wetting angle. This suite involves simulations spanning wetting angles from non-wetting to perfectly wetting and viscosity ratios spanning from 0.01 through 100. Each simulation is initialized with a porous model that is fully saturated with a "blue" fluid, and a "red" fluid is then injected from the left. The simulation parameters are set such that the capillary number is 10, well above the threshold for viscous fingering, and with a Reynolds number of 0.2 which is well below the transition to turbulence and small enough such that inertial effects are negligible. Each simulation involves the "red" fluid being injected from the left at a constant rate such in accord with the specified capillary number and Reynolds number until the red fluid breaks through the right side of the model. As expected, the dominant effect is the viscosity ratio, with narrow tendrils (viscous fingering) occurring for small viscosity ratios with M ≪ 1, and an almost linear front occurring for viscosity ratios above unity. The wetting angle is found to have a more subtle and complicated role. For low wetting angles (highly wetting injected fluids), the finger morphology is more rounded whereas for high wetting angles, the fingers become narrow. The effect of wettability on saturation (recovery factor) is more complex than the expected increase in recovery factor as the wetting angle is decreased, with specific wetting angles at certain viscosity ratios that optimize yield. This complex phase space landscape with hills, valleys and ridges suggests the dynamics of flow has a complex relationship with the geometry of the medium and hydrodynamical parameters, and hence recovery factors. This kind of behavior potentially has immense significance to Enhanced Oil Recovery (EOR). For the case of low viscosity ratio, the flow after breakthrough is localized mainly through narrow fingers but these evolve and broaden and the saturation continues to increase albeit at a reduced rate. For this reason, the recovery factor continues to increase after breakthrough and approaches over 90% after 10 times the breakthrough time.

EFFECT OF LOW TEMPERATURE CO2 INJECTION IN HIGH TEMPERATURE OIL RESERVOIRS USING SLIMTUBE EXPERIMENT

2016 ◽  
Vol 78 (6-6) ◽  
Author(s):  
Zakaria Hamdi ◽  
Mariyamni Awang
Keyword(s):  
High Temperature ◽  
Low Temperature ◽  
Interfacial Tension ◽  
Oil Recovery ◽  
Early Stage ◽  
Recovery Factor ◽  
Effect Of Temperature ◽  
Co2 Injection ◽  
Sweep Efficiency ◽  
Injection Point

A set of slimtube experiments is designed and presented to study the effect of cold temperature CO2 on recovery factor in reservoirs with high temperature. The comparison of the results indicates the positive effect of temperature on recovery trend in early stage as well as ultimate recovery in different injection pressures. The approach is based on a long slimtube to show the effect of temperature on the recovery. The study considers different temperatures and pressures of injection and reservoir allowing both miscible and immiscible flooding of CO2. Using non-isothermal conditions, the results show that, lowering temperature of injection can yield in higher recovery in early stage significantly. Also, considering ultimate recovery, it is observed that low temperature CO2 injection into high temperature reservoir can result in slightly higher recovery factor than isothermal injection. The reason for recovery increase is mainly due to elimination of the interfacial tension between CO2 and reservoir fluids especially near the injection point. Another finding is that the minimum miscibility pressures is lowered by means of lowering the temperature of injection which is again caused by elimination of interfacial tension between CO2 and oil. This is important because forming a single phase can increase the ability of CO2 to extract different components of the crude oil as well as lowering viscosity of the mixture, resulting in a better sweep efficiency. It appears that using liquid CO2 in high temperature reservoirs can be a promising method for better oil recovery in high temperature reservoirs. 

FMM/GPU Accelerated BEM Simulations of Emulsion Flow in Microchannels

2013 ◽  
Author(s):  
Olga A. Abramova ◽  
Yulia A. Itkulova ◽  
Nail A. Gumerov
Keyword(s):  
Oil Recovery ◽  
Large Scale ◽  
Heterogeneous Computing ◽  
Three Dimensional ◽  
Industrial Applications ◽  
Computational Techniques ◽  
Graphics Processors ◽  
Two Phase ◽  
Scalable Algorithm ◽  
Wide Range

Modeling of motion of two-phase liquids in microchannels of different shape is needed for a variety of industrial applications, such as enhanced oil recovery, advanced material processing, and biotechnology. Development of efficient computational techniques is required for understanding the mechanisms of many effects in “liquid-liquid” systems, such as the jamming of emulsion flows in microchannels and blood cell motion in capillaries. In the present study, a mathematical model of a three-dimensional flow of a mixture of two Newtonian liquids of a droplet structure in microchannels at low Reynold’s numbers is considered. The computational approach is based on the boundary element method accelerated both via an advanced scalable algorithm (FMM), and via utilization of a heterogeneous computing architecture (multicore CPUs and graphics processors). To solve large scale problems flexible GMRES solver is developed. Example computations are conducted for dynamics of many deformable drops of different sizes in microchannels. The results of simulations and accuracy/performance of the method are discussed. The developed approach can be used for solution of a wide range of problems related to emulsion flows in micro- and nanoscales.

A Microvisual Study of the Displacement of Viscous Oil by Polymer Solutions

2011 ◽  
Vol 14 (03) ◽  
pp. 269-280 ◽  
Author(s):  
M.. Buchgraber ◽  
T.. Clemens ◽  
L. M. Castanier ◽  
A. R. Kovscek
Keyword(s):  
Polymer Solution ◽  
Oil Recovery ◽  
Polymer Solutions ◽  
Pore Space ◽  
Polymer Concentration ◽  
Water Injection ◽  
Sweep Efficiency ◽  
Improved Oil Recovery ◽  
Associative Polymers ◽  
Displacement Front

Summary Of the various enhanced-oil-recovery (EOR) polymer formulations, newly developed associative polymers show special promise. We investigate pore and pore-network scales because polymer solutions ultimately flow through the pore space of rock to displace oil. We conduct and monitor optically water/oil and polymer-solution/oil displacements in a 2D etched-silicon micromodel. The micromodel has the geometrical and topological characteristics of sandstone. Conventional hydrolyzed-polyacrylamide solutions and newly developed associative-polymer solutions with concentrations ranging from 500 to 2,500 ppm were tested. The crude oil had a viscosity of 450 cp at test conditions. Our results provide new insight regarding the ability of polymer to stabilize multiphase flow. At zero and low polymer concentrations, relatively long and wide fingers of injectant developed, leading to early water break-through and low recoveries. At increased polymer concentration, a much greater number of relatively fine fingers formed. The width-to-length ratio of these fingers was quite small, and the absolute length of fingers decreased. At a larger scale of observation, the displacement front appears to be stabilized; hence, recovery efficiency improved remarkably. Above a concentration of 1,500 ppm, plugging of the micromodel by polymer and lower oil recovery was observed for both polymer types. For tertiary polymer injection that begins at breakthrough of water, the severe fingers resulting from water injection are modified significantly. Fingers become wider and grow in the direction normal to flow as polymer solution replaces water. Apparently, improved sweep efficiency of viscous oils is possible (at this scale of investigation) even after waterflooding. The associative- and conventional-polymer solutions improved oil recovery by approximately the same amount. The associative polymers, however, showed more-stable displacement fronts in comparison to conventional-polymer solutions.

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