Investigation of Different Ionic Liquids in Improving Oil Recovery Factor ()
1. Introduction
Given the depletion of oil reservoir energy and the limited discovery of new reservoirs, petroleum researchers have begun seeking more efficient techniques; one of the most promising methods is Chemical Enhanced Oil Recovery (CEOR), which has been used over the last three decades. The entrapped oil can be recovered by introducing chemical fluids to the porous media to reduce the system’s Interfacial Tension (IFT), increase the capillary number, maintain mobility control, decrease oil viscosity, and change reservoir wettability [1] . In recent times, chemicals called Ionic Liquids have been used to enhance the oil recovery factor.
Many studies have measured the properties of ionic liquids at different concentrations mixed either with water or other solvents. These investigations discovered that some ionic liquid types are capable of increasing mixture viscosity [2] . Kelkar and Maginn (2007) found that the effect of the ionic liquid on viscosity depends on its concentration in the mixture [3] . It has been concluded from Lafo et al. (2013) studies that the brine viscosity increases by adding Trihexyl phosphonium chloride ionic liquid, which reduces the mobility ratio between heavy oil and brine, and results in a higher oil recovery [4] . The effect of ILs on some surface behaviors such as surface tension has not yet been thoroughly studied as an aspect of enhanced oil recovery. Surface tension values are used as indications of surface interactions at the liquid interfacial microstructure [5] . To enhance the oil recovery process, it was observed that IFT increases as the concentration of salt in the aqueous phase increases. A small amount of chemical such as surfactant in the aqueous solution has the effect of decreasing the interfacial tension with salinity [6] . The Critical Micelle Concentration (CMC) is one of the critical surface activity parameters and at this concentration, the surfactant solution cannot reduce the IFT and the SFT any further [7] [8] . The CMC value can be determined either from measuring the IFT [9] or SFT [10] .
Wettability is one of the major mechanisms that affect fluids flow in the reservoirs [11] . Limited studies have been carried out to demonstrate the effects of wettability alteration by ionic liquids. Bin-Dahbag et al. (2014) have done a series of flooding experiments on Berea sandstone samples by using different ionic liquids concentrations to investigate the wettability alteration [12] . It was concluded that ILs have the ability to shift the rock wettability from oil wet towards water wet as a result of the interaction between oil, rock, and IL [12] . A similar study was conducted by Mohammed and Babadagli (2016) to investigate the effect of several imidazolium ionic liquids to modify the wettability of oil-wet limestone and sandstone. Another study showed that ionic liquids were more efficient in changing the rock wettability than other surfacants [13] .
Few studies have demonstrated the results of extracting more oil from consolidated and unconsolidated samples by using several ILs mixed with synthetic water or chemicals as tertiary recovery. Regarding core flooding experiments, Bin-Dahbag et al. (2014) found that the injection of a mixture of Ammonium-based IL with brine into a core sample for tertiary recovery increased the RF for medium crude oil (API 28.77˚) by about 4.5 [% OOIP] compared to low salinity solution flooding [12] . When compared to ammonium-based IL and brine mixtures, imidazolium-based IL mixed with brine and injected into a core sample as a tertiary recovery mode was able to extract 13 [% OOIP] more [14] . Additionally, as a result of increasing ILs concentration in brine, the oil recovery factor from sandstone and carbonate reservoirs increases [15] . However, Alarbah et al. (2017) have found that the increase in the RF was not economical when the IL [EMIM][Ac] concentration rose beyond the optimum concentration [16] .
In this research, flooding experiments were used to study the ability of introducing the [EMIM][Cl], [BenzMIM][Cl], and [THTDPh][Cl], at room temperature, various oil concentration mixed with Weyburn produced water into an unconsolidated sand pack. Moreover, the effect of IL on SFT, displacing phase viscosity, and pH were also measured for the IL mixtures. Finally, the impact of IL on wettability alteration was investigated.
2. Experimental Work
2.1 Materials
The oil sample used for the studies was taken from Weyburn crude oil with (30.25 API˚ and 15.35 cP). The properties of the oil and the Saturates, Aromatics, Resins and Asphaltenes (SARA) fractions are presented in Table 1. Weyburn brine (56,000 ppm) was used for the initial saturation of the sand-pack samples and flooding experiments. ([EMIM][Cl], 98 wt%), ([BenzMIM][Cl], 97 wt%), and ([THTDPh][Cl], 95 wt%) were used to investigate their efficiency on improving oil recovery factor). These chemicals were purchased from Sigma-Aldrich and used without any additional purification. The chemical structures of the employed ILs are shown in Figure 1. Also, different displacing fluids were made in the laboratory by mixing brine with the above mentioned chemicals that were later used in sand-pack flooding experiments, Table 2 shows the properties of aqueous solutions. Ottawa sand, 40 - 80 mesh, was used to prepare the unconsolidated sand-pack.
2.2 Experimental Apparatus
The apparatus used in this study consists of the following components:
Physical model: The physical model consisted of 18.75 cm steel core holder with 4 cm inner diameter.
Injection and pressure monitoring system: The conventional core flooding system was used with a 500 D syringe pump to inject the fluids into the sand pack. The pump was connected to three transfer cylinders each with a floating piston with a capacity of 900 cm3 containing brine, or oil, or chemical mixtures. The pressure data for each experiment was measured with a Heise Pressure
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Table 1. Properties of the Weyburn at 21.5˚C ± 1.
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Table 2. Properties of Aqueous Solutions.
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Figure 1. The Chemical Structures of Ionic Liquids.
Transducer, which calibrated the pressure drop across the core samples during the flooding process.
Production system: The core holder effluent was collected in 10 ml glass tubes at atmospheric conditions (101.325 kPa and 21.5˚C ± 1˚C). The oil and water were mixed at collection time and centrifuged through a Benchmark 2000 centrifuge.
Pores media and Displacing Fluids: By using sieve analysis, the average size of Ottawa sand was controlled at 40 - 80 mesh. The displaced fluids’ properties were measured by the subsequent apparatus. A digital weight meters quantified the digital masses of specific chemicals, which were added to the brine to prepare the displacing phases. Then, the solutions were stirred for 30 - 45 minutes at a speed of 120 rpm to allow the IL solutions to mix adequately. The polymer solutions were stirred for 24 hrs at 60 rpm. The viscosities of displacing fluids were measured by DV-II + Pro viscometer (supplied by Brookfield) with a temperature controller water-path. In order to measure the densities, the Anton Paar DSA 500 M instrument was used. A KRUSS K100 device was utilized to measure the SFT of the displacing mixtures by using the Wilhelmy plate method; a Cole-Parmer water path was implemented to control the temperature). The pH and conductivity values of the displacing phases were measured with a pH/COND Meter (supplied by HORIBA).
2.3. Experimental Procedure
A preparatory stage during which all apparatus were cleaned and calibrated was undertaken prior to research implementation. The following paragraphs describe in detail the preparatory stages:
Packing Procedure: A vertically-oriented core holder was packed utilizing the dry-packing method, using (40 - 80 mesh) Ottawa sand with consistent sand size parts. The core sample was vibrated during the packing process to distribute, therefore making the sand grains uniform in the core holder. The sand-pack sample was 100% vacuumed by using vacuum pump for approximately 10 hrs (until no bubble appeared); this step was preceded by packing the sand and fixing the cap after which the weight was measured. Subsequently, the model was connected to the pump and fully saturated with Weyburn brine. Then the porosity and the absolute permeability were calculated. The average petrophysical properties of the sand-pack samples are presented in Table 3.
Saturation Process: After finishing the routine core analysis, both the core holder and the core flooding system were connected vertically to determine the irreducible water saturation and the initial oil saturation, at a rate of 1 cm3/min. The sand-pack flooded with medium oil until no free water seeped out from the core holder outlet. The total displaced brine represents the initial oil saturation (Soi) while the remaining brine represents the irreducible water saturation (Swi). The moment that the core sample was thoroughly saturated with oil, determined that the sand pack was ready for the flooding experiments.
Flooding Procedure: In this stage, the cores were positioned horizontally and flooded with either ILs, or polymer mixtures alone or ILs, and polymer mixture. For one of the scenarios the core samples were initially flooded with 1 pore volume of chemicals mixture then flushed by two pore volumes of brine. The optimum flow rate (2 cm3/min) was applied as injection rate for flooding experiments that were done to investigate the effect of chemical concentration, the chemical solution slug size, the initiation time for injecting the chemical mixture as well as the flow rate that was obtained from previous study [16] .
The produced oil and water samples from the sand pack were collected in graduated tubes and then placed in a separator to determine the exact amount of recovered oil. The total oil recovery factor was expressed as the ratio of produced oil to the original oil in place.
Subsequently, all the above-mentioned procedures were carried out at room temperature (21.5˚C ± 1˚C), and they all have been repeated with unused sand to ensure the consistency.
3. Results and Discussion
Effect of IL Type on RF: To test the effectiveness of ILs on the enhanced oil
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Table 3. The average petrophysical properties of the sand-pack samples.
recovery, different types of ionic liquids, [EMIM][Cl], ([BenzMIM][Cl]), and [THTDPh][Cl], were investigated by flooding IL mixtures at selected optimum concentration (1000 ppm), slug size (1 PV), and slug initiation time (as secondary mode) based on the data obtained from previous research [16] . The flooding for each core sample was per pore volume with one of ILs mixtures at the first stage, and later 2 PVs of the brine flushed. As shown in Figure 2, the recovery factor curves rose dramatically with the injection of 1000 ppm IL mixtures until the breakthrough. The breakthrough occurred when the samples were flooded with 1000 ppm of [EMIM][Cl], [BenzMIM][Cl], and [THTDPh][Cl] mixtures for 0.417 PV, 0.401 PV, and 0.398 PV Injected, respectively. After the breakthrough, the recovery factors increase gradually and mainly depend on the Ionic Liquid type. The total RFs obtained from injecting 1000 ppm [EMIM][Cl], [BenzMIM][Cl], and [THTDPh][Cl] were 78.36 [% OOIP], 75.01 [% OOIP], and 75.15 [% OOIP], respectively. However, the results that were obtained from using ILs mixtures in the flooding process were superior to those generated from injecting brine alone. The difference in oil recovery improvement could be due to the effect of Ionic Liquids on displacing phase viscosities, and surface tension as shown on Table 4.
Effect of IL Critical Micelle Concentration on RF: In order to determine the Critical Micelle Concentration (CMC) of ILs, the surface tension (SFT) was examined in displacing solutions at room condition. The CMC point that was obtained when [EMIM][Cl] was added to brine was 2500 ppm as shown in Figure 3. For the other two-studied ILs ([BenzMIM][Cl] and [THTDPh][Cl]), it was found that both of them have similar effectiveness in terms of reducing surface tension. The SFT values, as shown in Figure 4 and Figure 5, decrease when increasing the concentration of [BenzMIM][Cl] and [THTDPh][Cl] to 1500 ppm
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Figure 2. Ionic liquid type effect on the recovery factor.
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Figure 3. ([EMIM][Cl]) effect on Displacing phase SFT.
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Figure 4. ([BenzMIM][Cl]) effect on Displacing phase SFT.
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Figure 5. [THTDPh][Cl] effect on Displacing phase SFT.
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Table 4. Properties of IL Mixtures at 1000 ppm.
after which the values grow slightly. Evidently, 1500 ppm of [BenzMIM][Cl] and [THTDPh][Cl] in the mixture produces the highest SFT reduction and it is considered as the CMC value of both ILs.
To investigate the effect of the ILs’ CMC on extracting more oil, the CMC for each of these ILs was mixed with brine and injected into the sand pack. The flooding procedure was similar to the optimum scenario obtained from the previous experiments. As presented in Figure 6, the results showed that the effectiveness of adding the CMC of the ILs [EMIM][Cl], [BenzMIM][Cl], and [THTDPh][Cl]) to brine and flooding the mixture into the sand packs, more oil was able to be extracted than when 1000 ppm of the same ILs mixtures were injected. The additional RF values of injecting the CMC of [EMIM][Cl], [BenzMIM][Cl] and [THTDPh][Cl] were 1.74 [% OOIP], 2.50 [% OOIP], and 1.41 [% OOIP], respectively. This enhancement of oil recovery could be due to the reduction in SFT and slight increase in viscosity as presented in Table 5. Overall, the results indicate that using the CMC of ILs and when mixed with brine was efficient in improving the RF.
pH Behaviors: The pH values of the displacing phase mixtures used in this study were measured at room temperature. It is per another study that an increment in increasing [EMIM][Ac] concentration in the mixtures lead to an increase in the PH value of the solutions whereas the effect of temperature was minimal [17] . As anticipated, the increase in water content led to declining the PH values of extraction mixtures. This is presented in the previous Table 4, and Table 5).
Effect of Wettability Alterations on RF: To investigate the effect of ILs on the wettability of the studied sand packs, relative permeability (Kro & Krw) curves were plotted based on the following four flooding experiments: 3 PVs of CMC values (2500 ppm, 1500 ppm, 1500 ppm) of ILs [EMIM][Cl], [BenzMIM][Cl] and [THTDPh][Cl]) mixtures. They were injected into unconsolidated samples under the same conditions, respectively. As indicated in Figure 7. The total RF values were increasing in the following order: Brine (73.27 [% OOIP]) < [THTDPh][Cl] (79.21 [% OOIP]) < [BenzMIM][Cl] (80.01 [% OOIP]) < [EMIM][Cl] (82.67 [% OOIP]). These differences in RF values could be due to the differential impact of ionic liquids on wettability. The Kro and Krw during these runs were measured by using the relative permeability graphical technique. This method was elaborated by Jones and Roszelle [18] . Relative permeability curves, as presented in Figure 8, clearly show that the maximum shift in Kro and Krw intersection (Sw = 0.82, Kro and Krw = 0.08) was obtained after flooding 3 PV of 1500 ppm [BenzMIM][Cl].
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Figure 6. Effect of CMC of Ionic liquids on RF.
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Figure 7. Effect of CMC Ionic liquids on RF in Continuous Secondary Recovery Mode.
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Figure 8. Relative permeability curve, Brine and [BenzMIM][Cl] Solution.
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Table 5. Properties of ILs Mixtures at CMC.
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Figure 9. Relative permeability curve, Brine and [EMIM][Cl] Solution.
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Figure 10. Relative permeability curve, Brine and [THTDPh][Cl] Solution.
The intersection point of the relative permeability curves was reduced further with the injection of 2500 ppm of [EMIM][Cl] mixture, and the intersection point between the Kro and krw curves had a Sw value of 0.66 and 0.10 for both Kro and Krw, as shown in Figure 9. The minimum shift to the right occurred when 1500 ppm of [THTDPh][Cl] mixture was injected and the intersection point between the Kro and Krw curves had a Sw value of 0.64 and 0.09 for both Kro and Krw, as shown in Figure 10. From two phases, water oil relative permeability as a function of water saturation, there is an inverse proportion relation between rock water wetness and residual saturation when IL solution flooding is applied as compared to brine flooding. This proves that enhancement in the RF results of this study is due to wettabiltity alteration mechanism as well.
4. Conclusions
The following conclusions were reached based on the experimental results obtained in this study:
1) ILs proved to be efficient when used to enhance medium oil recovery. It is evident that the efficiency of ILs depends on the IL types and concentration.
2) Regarding IL concentration, it was observed that the RF increased as the concentration of IL in the displacing phase increased. Moreover, the optimum concentration depended on the type of IL.
3) In this study, it was found that [EMIM][Cl] is the most effective ionic liquid for enhancing medium oil recovery in comparison with the other three ILs.
4) The oil recovery was increased when the ionic liquids were added to the displacing phase due to reduction in mobility ratio and surface tensions of displacing fluids. Additionally, the ionic liquids used had the ability to improve the wettability of the rocks to become more water wet.