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Chemical flooding has been found to be one of the major EOR techniques especially for reservoirs where thermal methods are not feasible. The application of chemical flooding is strongly influenced by the current economics, type of reserve oil and crude oil price. In this paper, an up to date status of chemical flooding at the laboratory scale, pilo...
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... et al. (2009) developed a simulation technique to simulate and match the experimentally measured pressure drop and cumulative oil production during the alkaline flooding processes by incorporating both the measured W/O emulsion viscosity and relative permeability. A comparative picture of oil recovery by surfactant flooding after conventional water flooding at the laboratory scale has been presented in Table 1. The additional recovery after water flooding depends on the type of crude oil, petro-physical properties of core/sandpack and dosing of alkali. ...
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Over time, the dependence on oil has increased to meet industrial and domestic needs. Enhanced oil recovery (EOR) techniques in this regard have captured immense growth as EOR is not only used to increase the oil recovery but also to augment the sweep efficiency. Several techniques over the past decades have been used to improve oil recovery with c...
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... Due to its ability to increase viscosity (a reduction in mobility) of the injecting fluid, its application has extended to enhancing oil recoveries in medium to heavy oil reservoirs with a smooth flood front without viscous fingering. Extensive experimental polymer flooding options have been carried out by Ref. [11] and the results recorded have shown an average substantial increase in oil recovery of 11 %. ...
... In this technique a combination of chemicals like alkali, surfactant, and/or polymers are used to change the physicochemical characteristics of reservoir rock and contained fluids, like; interfacial tension, wettability and relative permeability. Altering of the mentioned properties causes to recover residual oil that trapped within capillaries of the reservoir rocks [30]. In chronological order, chemical EOR methods are divided into two groups; (i) conventional techniques like alkaline flooding, polymer flooding, and surfactant flooding, and (ii) modern techniques like alkaline-surfactant-polymer (ASP) flooding, smart polymers and nanotechnology. ...
... An illustration of alkaline flooding EOR technique (by permission of Mandal[30]) ...
As we all know, numerous methods have been invented for better managing of the reservoirs to recover the trapped oil from them as much as possible. These techniques included primary techniques that were implemented primarily at the beginning of this industry. As these techniques were not effective enough, secondary techniques, like; water flooding and gas injection methods were created and the amount of recovered oil were increased, as well. On the contrary, the demand for more oil was raised up and it was felt that much more effective techniques are necessary. It resulted to creation of Enhanced Oil Recovery Techniques and these techniques are included; thermal methods (steam injection, steam assisted gravity drainage and in-situ combustion), Chemical methods (alkali flooding, surfactant flooding, polymer flooding, foam flooding, and combination of alkali-surfactant-polymer flooding), and microbial EOR. The most promising technique is microbial EOR because of being cost-effective and ecofriendly. GEMEOR (Genetically Engineered MEOR) and EEOR (Enzyme Enhanced Oil Recovery) are two new trends of MEOR that own potential hopes in petroleum industry.
... A variety of enhanced oil recovery (EOR) techniques have been developed, which are classified into chemical, gas injection, and thermal. Chemical EOR methods are based on the injection of chemical compounds [2]. Chemical EOR methods are categorized into the injection of surfactants, polymers, and alkaline/surfactant/polymer (ASP) [3][4][5]. ...
... On the other hand, as described in Section 3.3 multi-metal catalyst converts long hydrocarbon chains into shorter chains. Since the vapor pressure of the lighter hydrocarbons is higher, according to equation (2), an increase the amount of lighter hydrocarbons rise the vapor pressure and consequently rise partial pressure and finally increases the total pressure [81]. ...
Due to the high costs and associated high CO2 emissions of thermal methods, this study focuses on upgrading heavy oil and enhancing oil recovery within reservoir temperature ranges. In this research, a novel, low-cost, and environmentally friendly multi-metal catalyst has been used, which is actually extracted from electronic waste (E-waste). At optimal conditions, which include 80 °C, 12 h of retention time, and 0.2 % v/v of the multi-metal catalyst, this catalyst effectively reduced the viscosity of heavy oil from 687 to 580 mPa.s. To analyze heavy oil before and after the process, Fourier transform infrared spectroscopy (FTIR) was conducted. FTIR spectra indicates that the multi-metal catalyst has reduced the amount of aromatic compounds, shortened hydrocarbon chains, and decreased double and triple bonds. Micromodel tests were conducted by multi-metal catalyst flooding at optimal temperature and retention time obtained from static experiments. Heavy oil recovery through multi-metal catalyst flooding reached 38 %, which is a 10.5 % increase compared to deionized water flooding. The contact angle of the rock was measured after contact with the multi-metal catalyst. The multi-metal catalyst reduced the contact angle by 55 °, changing the wettability of carbonate rock from oil-wet to water-wet. The absorption test indicates that the multi-metal catalyst dissolves certain metals in the rock, most likely due to the high pH of the catalyst. As a result, the permeability of the rock may increase due to the dissolution of the rock metals.
... 23−25 Alkalis and surfactants are commonly utilized in chemical-based oil recovery techniques to enhance both the microscopic and macroscopic sweep efficiency of oil. 26,27 Alkaline/surfactant (AS) flooding is a proven chemical flooding technique that has been shown to be successful in increasing the recovery of oil from fields that have been depleted. ...
Over time, oil consumption has increased along with a continuous demand for petroleum products that require finding ways to increase hydrocarbon production more economically and effectively. So, enhanced oil recovery technologies are believed to be very promising and will serve as a key to meeting the future energy demand. This paper aims to introduce an innovative method to boost the EOR by using two novel types of surfactants synthesized from sulfonamide derivatives. Types I and II surfactants were analyzed using Fourier transform infrared spectroscopy, and their characterization was further performed using 1H NMR and 13C NMR spectroscopy. Additionally, the evaluation of these surfactants included interfacial tension measurements at concentrations up to 0.9 wt %. The combination of types I and II surfactants with alkaline (NaOH) was also investigated by the measurements of interfacial tension. A series of coreflood and sandpack tests under high-salinity conditions were carried out to assess the effects of a surfactant alone and alkaline–surfactant as a combination on improving oil recovery. The rock wettability was evaluated using relative permeability saturation curves, and the oil displacement efficiency was determined using fractional flow curves. The coreflood results demonstrated that alkaline–surfactant flooding with the chemical formula 0.2 wt % surfactant type II plus 0.5 wt % NaOH achieved a higher oil recovery of 74% OOIP compared to surfactant flooding with the chemical formula 0.5 wt % surfactant type II (64% OOIP) and waterflooding (saline solution with a 35,000 ppm salinity: 48% OOIP). Moreover, the experimental results showed that under both core and sandpack flood conditions, there was a noticeable reduction in oil–water interfacial tension, a change in rock wettability to more water-wet, and higher efficiency of oil displacement when alkaline was added to the surfactant. Based on current research, the alkaline–surfactant formulation is strongly recommended for chemical flooding because of its high efficacy and relatively low cost.
... viscosity of heavy oil [3,5,6]. However, chemically enhanced oil recovery (cEOR) can be strengthened by the use of chemical additives [7][8][9][10]. In cEOR, common chemical additives are surfactants, polymers, bases, and their complex systems. ...
Heavy oil exploitation needs efficient viscosity reducers to reduce viscosity, and polyether carboxylate viscosity reducers have a significant viscosity reduction effect on heavy oil. Previous work has studied the effect of different side chain lengths on this viscosity reducer, and now a series of polyether carboxylate viscosity reducers, including APAD, APASD, APAS, APA, and AP5AD (the name of the viscosity reducer is determined by the name of the desired monomer), with different electrical properties have been synthesized to investigate the effect of their different electrical properties on viscosity reduction performance. Through the performance tests of surface tension, contact angle, emulsification, viscosity reduction, and foaming, it was found that APAD viscosity reducers had the best viscosity reduction performance, reducing the viscosity of heavy oil to 81 mPa·s with a viscosity reduction rate of 98.34%, and the worst viscosity reduction rate of other viscosity reducers also reached 97%. Additionally, APAD viscosity reducers have the highest emulsification rate, and the emulsion formed with heavy oil is also the most stable. The net charge of APAD was calculated from the molar ratio of the monomers and the total mass to minimize the net charge. While the net charge of other surfactants was higher. It shows that the amount of the surfactant’s net charge affects the surfactant’s viscosity reduction effect, and the smaller the net charge of the surfactant itself, the better the viscosity reduction effect.
... Polymer flooding is a method of oil production that uses synthetic or bio polymers to increase oil production by improving the mobility ratio between displacing fluid and oil (Mandal, 2015). Hence, the oil displacement by aqueous solution occurs due to increased water viscosity by adding polymers. ...
Polymer flooding is crucial in hydrocarbon production, increasing oil recovery by improving the water-oil mobility ratio. However, the high viscosity of displacing fluid may cause problems with sand production on poorly consolidated reservoirs. This work investigates the effect of polymer injection on the sand production phenomenon using the experimental study and numerical model at a laboratory scale. The experiment uses an artificially made sandstone based on the characteristics of the oil field in Kazakhstan. Polymer solution based on Xanthan gum is injected into the core to study the impact of polymer flooding on sand production. The rheology of the polymer solution is also examined using a rotational rheometer, and the power-law model fits outcomes. We observe no sand production during the brine injection at various flow rate ranges. However, the sanding is noticed when the polymer solution is injected. More than 50% of cumulatively produced sand is obtained after one pore volume of polymer sand is injected. In the numerical part of the study, we present a coupling model of DEM with CFD to describe the polymer flow in a granular porous medium. In the solid phase, the modified cohesive contact model characterizes the bonding mechanism between sand particles. The fluid phase is modeled as a non-Newtonian fluid using a power-law model. We verify the numerical model with the laboratory experiment result. The numerical model observes non-uniform bond breakage when only a confining stress is applied. Alternatively, the injection of the polymer into the sample leads to a relatively gradual decrease in bonds. The significant difference in the pressure of the fluid results in its higher velocity, which causes intensive sand production at the beginning of the simulation. The ratio of medium-sized produced particles is greater than the initial ratio of those before injection.
... Among various types of enhanced oil recovery (EOR) techniques, chemical EOR (CEOR) has received a great deal of attention, particularly in the past few decades [1,2]. In this respect, surfactants of various types have widely been utilized to lower interfacial tensions at fluid-fluid and rock-fluid interfaces [3,4]. However, environmental concerns and the inefficiency of surfactants under harsh reservoir conditions, i.e., high salinity and high temperature, have compromised their application [5]. ...
Chemical injection has proved to have superior performance in improving oil recovery. The injected chemicals are typically designed to participate in interfacial interactions at liquid-liquid and rock-liquid interfaces while having minimum adsorption onto the rock surface. This study endeavors to investigate the interfacial activity of several environmentally-friendly halogen-free ionic liquid-based catanionic surfactants synthesized via an ion exchange reaction between cationic imidazolium-based ionic liquids, [C n mim][Cl] (n = 4,8,12), and anionic surfactants, sodium dodecyl sulfate, sodium dodecylbenzene sulfonate, and dioctyl sodium sulfosuccinate. Results revealed that the catanionic surfactant synthesized with medium-chain ionic liquid (n = 8) and sodium dodecyl sulfate exhibited higher interfacial activity, demonstrating a minimum crude oil-brine interfacial tension of 0.17 mN/m and wettability alteration index of 0.79. The results of the adsorption study also revealed the adsorption density of 2.19 mg/g onto the dolomite surface for 2000 mg/L of catanionic surfactant in seawater, which was considerably lower than cetyltrimethylammonium bromide adsorption (11.55 mg/g) in the control experiment. Finally, the surface energy analysis of liquid-rock interactions was conducted using the concept of work of adhesion to scrutinize the wettability alteration and adsorption processes, where a direct relationship between work of adhesion and adsorption density was proposed. According to the results of this study, medium chain ionic liquid-based catanionic surfactant containing dodecyl sulfate anion, exhibiting excellent interfacial activity and low adsorption tendency onto the dolomite surface, could be considered in future chemical enhanced oil recovery applications.
... Among these non-thermal methods, chemical flooding EOR (CEOR) achieves good oil recovery and has drawn interests. Normally, alkali, surfactants, polymers and their mixtures are injected to reservoirs in CEOR process [70]. Alkali flooding was the earliest chemical EOR method, which was first proposed in 1917 and proved by experiments in 1930 s. ...
... The total available reserves of hydrocarbon are constant and the number of new fields being discovered has been consistently decreasing every year (Toscano et al. 2016). With nearly two-thirds of the oil remains trapped in the reservoir after primary and secondary recovery (Gbadamosi et al. 2018), getting optimum recovery from the existing reserves has become more important than looking for new ones (Gbadamosi et al. 2019;Mandal 2015;Pope 2011;Rezk and Allam 2019). ...
Nanoemulsions are kinetically stable emulsions with droplet size distribution in the range of 10–500 nm. Low interfacial tension (IFT), small droplet size, and wettability alteration properties of nanoemulsions have led to their application for enhanced oil recovery (EOR) EOR. The current study deals with the formulation and characterization of Tergitol 15-S-9 surfactant stabilized oil/water nanoemulsion (NE). Optimal surfactant concentration accompanied by optimal salinity determination was done by observing long-term stability. The stability of the nanoemulsions was analyzed by Turbiscan and Zeta potential analysis. The optimal nanoemulsion was characterized in terms of droplet size, rheology, wettability, miscibility, and IFT. All the prepared nanoemulsion showed particle size < 300 nm. optimized nano emulsion, that is, 0.5 wt.% surfactant +0.5 wt.% salinity showed good IFT reduction and wettability alteration capability. Nanoemulsion also showed good miscibility behavior with actual crude oil at 60 °C. Rheology of the formed emulsion shows a mixed nature that is shear thinning as well as shear thickening nature which is favorable for heterogeneous reservoirs. Core-flooding experiments were conducted at optimized nanoemulsion formulation, and additional oil recovery of 13.93% of the original oil in place was obtained after the conventional water flooding.
• Highlights
• Experimental and mechanistic investigation of nanoemulsions for oil recovery.
• Enhanced miscibility of Tergitol 15-S-9 stabilized nanoemulsion with crude oil.
• Viscosity enhancement by macromolecular and supramolecular network structures.
• Low IFT achieved for the nanoemulsion resulting enhanced oil displacement.
• Encouraging oil displacement by injection of formulated nanoemulsion.
... With the advancement of tertiary oil recovery technology in recent years, the excellent properties of surfactants in improving oil recovery have been fully recognized. The chemical flooding method, in which surfactants are added to the flooding fluid, is considered to be one of the most effective means to improve oil recovery [1][2][3][4]. Research on the structureactivity relationship of surfactants used in oil displacement has aroused the continuous interest of scholars at home and abroad, particularly the optimization of the oil displacement system in high temperature, high salt and low permeability reservoirs [5][6][7]. Compared with conventional oil reservoirs, low permeability restricts the efficient use of polymers for oil displacement. ...
Micro visualization has become an important means of solving colloid and interface scientific problems in enhanced oil recovery. It can establish a relationship between a series of performance evaluations of an oil-water interface under macroscopic dimensions and the actual application effect in confined space, and more truly and reliably reflect the starting and migration behavior of crude oil or emulsion in rock pores. In this article, zwitterionic surfactant alkyl sulfobetaine (ASB) and anionic extended surfactant alkyl polyoxypropylene sulfate (A145) were employed as flooding surfactants. The macroscopic properties of the surfactant solutions, such as the oil-water interfacial tension (IFT), the interfacial dilational rheology and the viscosity of crude oil emulsions, have been measured. At the same time, we link these parameters with the oil displacement effect in several visual glass models and confirm the main factors affecting the migration ability of emulsions in micro-scale pores. The experimental results show that ASB reduces the IFT through mixed adsorption with crude oil fractions. The flat arrangement of the large hydrophilic group of ASB molecules enhances the interactions between the surfactant molecules on the oil-water interface. Compared with sulfate, betaine has higher interfacial membrane strength and emulsion viscosity. A145 has a strong ability to reduce the IFT against crude oil because of the larger size effect of the PO chains at the oil side of the interface. However, the membrane strength of A145 is moderate and the emulsion does not show a viscosity-increasing effect. During the displacement process, the deformation ability of the front emulsions or oil banks is the main controlling factor of the displacement efficiency, which is determined by the membrane strength and emulsion viscosity. The strong interfacial membrane strength and the high emulsion viscosity are not conducive to the migration of droplets in pore throats and may result in low displacement efficiency.
