Research for reducing the Minimum Miscible Pressure of crude oil and carbon dioxide by injecting citric acid isobutyl ester
Department of Petroleum Engineering, Northeast Petroleum University, Daqing 163318, China
2 Key Laboratory of Enhanced Oil Recovery (Northeast Petroleum University), Ministry of Education, Daqing 163318, China
3 School of Earth Sciences, Northeast Petroleum University, Daqing 163318, China
* Corresponding author: firstname.lastname@example.org
Accepted: 24 February 2021
Carbon dioxide miscible flooding has become one of the important technologies for improving oil recovery. The Minimum Miscible Pressure (MMP) is the key parameter to realize miscible flooding. As the MMP in the research area is higher than the formation fracture pressure, miscible flooding cannot be formed. To address this problem, it is necessary to find a way to reduce the MMP. Citric acid isobutyl ester is chosen to reduce the MMP of carbon dioxide and crude oil in this research. The effect of citric acid isobutyl ester on reducing the MMP was measured by the method of long-slim-tube displacement experiment. The experiment results show that the MMP is 29.6 MPa and can be obviously reduced by injecting the slug of citric acid isobutyl ester. The MMP could decrease gradually with constantly adding the injected slug of citric acid isobutyl ester, but the decrease becomes smaller and smaller. The optimum injected slug size of the chemical reagent is 0.003 PV. Under the condition of the slug size, the MMP is reduced to 23.5 MPa and the reduction is 6.1 MPa.
© G. Fan et al., published by IFP Energies nouvelles, 2021
This is an Open Access article distributed under the terms of the Creative Commons Attribution License (https://creativecommons.org/licenses/by/4.0), which permits unrestricted use, distribution, and reproduction in any medium, provided the original work is properly cited.
There are lots of successful cases by injecting carbon dioxide (CO2) to improve oil recovery in America, Russia, Canada, China, and so on. The carbon dioxide injection technology has become an Enhanced Oil Recovery (EOR) technology that is widely applied in the world [1–5]. It is more suitable for most low permeability oil fields to be developed by gas injection [6–9]. Carbon dioxide injection has the advantages of wide application, low cost, significantly improved oil recovery [10–12]. At the same time, carbon dioxide flooding can solve the problem of carbon dioxide sequestration to a certain extent, reduce greenhouse gas emissions into the atmosphere, and alleviate the pressure of the environmental pollution [13–18]. So under the background of energy shortage, energy conservation and emission reduction, carbon dioxide flooding has a broad application prospect [19–23]. Indoor experiment and field test show that the effect of carbon dioxide miscible flooding to improve oil recovery is better from light to intermediate viscosity crude oils than that of immiscible flooding [24–28]. However, miscible flooding cannot be fully realized in some oil field blocks if the Minimum Miscible Pressure (MMP) is higher than the reservoir pressure [29, 30]. To address this problem, it is necessary to find a way to reduce the MMP.
Low-molecular-weight non-ionic surfactant method: Guo et al. selected CAE and CAF as non-ionic surfactants to reduce the MMP, and investigated the oil solubility, solubility in supercritical CO2 and viscosity reduction of the two reagents. The results show that such surfactants can reduce the MMP .
Miscible solvent method: In this method, the miscible solvent is injected into the ground and diffused in the formation to dissolve with the crude oil to form a miscible displacement zone; the injected CO2 gas comes into contact with the miscible zone to achieve miscibility at low pressure, so as to improve the oil recovery [34, 35]. Zhang et al. carried out a large number of experiments on single-component methanol, ethanol, n-hexane, n-octane, and multi-component petroleum ether, light oil and other miscible solvents . Peng et al. injected a certain ratio of liquefied gas into CO2 to study its influence on the miscible pressure of CO2 flooding .
CO2-philic non-ionic surfactant method: Such surfactants proposed in domestic and foreign literature are mainly siloxanes and fluorides [36–38]. Due to the high solubility in CO2, the fluoride surfactant has good affinity with CO2. For example, the Perfluoroalkylpolyether (PEPE) surfactant [39, 40], which can reduce the surface tension between CO2 and water to a very low level, is the most effective CO2-philic surfactant at present. Hoefling and other scholars discovered that PEPE has better solubility in supercritical CO2 . DeSimone and Keiper found that polyacrylic acid 1, 1-dihydro-Perfluorooctanoic Acid (PFOA) has strong CO2-philic performance, then synthesized the block polymer surfactant of PFOA and Polystyrene (PS), and developed the supercritical CO2 cleaning technology .
Supercritical CO2 microemulsion method: In this method, the MMP is reduced by using the surfactant dissolved in supercritical CO2 to form nanoscale aggregates [43, 44]. Both the supercritical and microemulsion technologies are needed for the supercritical CO2 microemulsion technology to reduce the miscible pressure of CO2 flooding. Dong and other scholars obtained the supercritical CO2 microemulsion using the Di-(2-ethylhexyl) sodium sulfosuccinate (AOT) as surfactant, ethanol as auxiliary, and the MMP between supercritical CO2 microemulsion and alkane was investigated, including alkane carbon number, temperature, surfactant addition and other factors . Dong et al. studied the MMP between supercritical CO2 microemulsion and Daqing heavy oil .
According to the carbon dioxide pilot test results of the research area, the gas injection can realize stable injection with low pressure, which solves the problems of water flooding difficulty of the ultra-low permeability reservoir. Producing wells got the apparent effect and higher production levels in the case of gas injection. However, the overall oil production speed is slow. According to the result of long-slim-tube displacement experiment, the MMP of the research area is 29.6 MPa that is higher than the reservoir pressure, so that the research area cannot form the miscible flooding as a whole [46, 47]. Therefore, the research for reducing the MMP of carbon dioxide miscible flooding can carve out a new way for comprehensive realization of miscible flooding to significantly improve oil recovery in research area . Citric acid isobutyl ester is chosen to reduce the MMP of carbon dioxide and crude oil of research area in this research .
The crude oil used in the experiment is the simulated crude oil prepared by the surface oil and natural gas in the research area according to the formation conditions and fluid characteristics. The experiment temperature is 108.5 °C. The viscosity of crude oil is 1.88 mPa s at 108.5 °C and 23.8 MPa that are the temperature and the pressure of the formation. The molecular weight of C7+ in crude oil composition is 347.29 g/mol, and the density of C7+ is 0.8971 g/cm3. The purity of carbon dioxide gas is 99.9%, and the properties are exactly the same as that of carbon dioxide injected in the research area.
The experimental apparatuses mainly include: the piston container of carbon dioxide, the piston container of simulated crude oil, the piston container of formation water, slim tube filled with quartz sand particles, liquid flowmeter, gas flowmeter, back pressure control valve. The sketch of experimental apparatus and flow chart are shown in Figure 1. The photos of long-slim-tube displacement experimental apparatus are shown in Figure 2.
The sketch of long-slim-tube displacement experimental apparatus.
The photos of long-slim-tube displacement experimental apparatus.
The injection pump is ISCO full automatic pump, which is manufactured by Teledyne ISCO Corporation of American. The working pressure range is 0–70 MPa and the accuracy is 0.01 mL. The working pressure range of back pressure control valve is −70 MPa. The highest temperature of constant temperature box is 200 °C. The accuracy of gas flowmeter is 1 mL. The long slim tube is a one-dimensional artificial porous medium spiral stainless steel coil tightly filled with approximately 200 mesh of pure quartz sand. The experimental parameters are shown in Table 1.
Basic parameters of the long-slim-tube displacement experimental model.
Indoor experiment formation oil is prepared with ground oil and natural gas. The process is to put a certain amount of ground oil into the high pressure physical instrument PVT barrel, seal it and heat it up to the formation temperature, then put the gas into the PVT barrel at the saturation pressure, stir and increase pressure to the formation pressure, measure the saturation pressure of crude oil and the dissolved gas-oil ratio. If the saturation pressure and the actual formation oil saturation pressure are not equal, we should adjust the amount of dissolved gas in the PVT barrel until the saturation pressure and gas-oil ratio measured are equal to that of the formation oil.
The methods of predicting the MMP generally include laboratory experiment and theoretical calculation [50–54]. Laboratory experiment methods include long-slim-tube displacement experiment method, interfacial tension method, Rising Bubble Apparatus (RBA) method and vapor density method. Theoretical calculation methods include empirical formula method, equation of state method [55, 56] and simulation calculation method. Among all the prediction methods, the long-slim-tube displacement experiment method has been widely used and recognized by researchers and scholars. The long-slim-tube displacement experiment is repeatable. Compared with other methods, this method is more in line with the characteristics of oil and gas displacement process in the porous medium of crude oil reservoir. Moreover, the influence of unfavorable factors such as heterogeneity, mobility ratio, viscous fingering and gravity separation of lithology can be eliminated to the greatest extent [57–59]. Therefore, the long-slim-tube displacement experiment method was used to determine the MMP in the research area.
Temperature setting: Turn on the power switch of the constant temperature box and heat up. When the temperature is close to the formation temperature, start the constant temperature controller. After 3 h, the temperature can be completely maintained at the predetermined value.
Tube cleaning: Saturate the slim tube model adequately with petroleum ether, and use high pressure air to blow dry the petroleum ether.
Import carbon dioxide: Open the pump and push the piston back to the top of the piston container to vent the gas from the container; inject the displacing gas carbon dioxide into the piston container and close the valve.
The long slim tube should be vacuumized. Then saturate the formation water into the sand filling slim tube and calculate the porosity.
Clean the formation water in the sand filling slim tube with toluene. Dry it in a thermostat to evaporate the toluene.
Saturate the simulated oil into the sand filling slim tube. Inject the simulated oil into the slim tube model with the ISCO constant-pressure and constant-speed pump. Stop the injection when the 1.5 PV simulated oil is injected. The injection and output of simulated oil are calculated. The amount of saturated oil injected into the tube is determined according to the volume difference. Then close the process and prepare for a displacement experiment.
Start the ISCO constant-pressure and constant-speed pump to increase the pressure of gas in the piston container, and make it 1~3 MPa lower than the displacement pressure.
Raise the back pressure to the predetermined displacement pressure through a manual pump.
Open the pump to inject carbon dioxide under constant pressure, open the slim tube outlet valve, and adjust the gas pressure to make it equal to or slightly higher than the displacement pressure.
In the process of displacement, determine oil production, gas volume and pump reading regularly as required, and check oil sample saturation. When the cumulative volume of the gas drive is greater than 1.2 PV, the displacement is stopped and the recovery under this pressure is calculated.
At the end of the displacement process, the cleaning process is started, and the petroleum ether is directly injected into the slim tube model, and the appropriate back pressure is maintained. The flow rate of petroleum ether in the slim tube is not too fast, so as not to affect the cleaning effect. Close the outlet for 1–2 h, and make the petroleum ether and residual oil fully contact each other under high pressure. Dissolve the residual oil in the petroleum ether, and release it from the outlet. Repeatedly, the mixture of petroleum ether and residual oil is discharged. When the mixture and the component of pure petroleum ether are basically the same, the residual oil in the model is determined to be completely removed and fully saturated with petroleum ether. Then, high-pressure air is injected from the inlet, and the remaining petroleum ether in the slim tube is blown into the oil-gas separator, and the pipeline is blown dry for the next experiment.
Follow the above steps for displacement at the next pressure point.
In general, the MMP can be analyzed by measuring the recovery at more than 5 pressure points. The experimental back pressures in experiment are 20 MPa, 25 MPa, 30 MPa, 35 MPa, 40 MPa and 45 MPa. Then the MMP is calculated according to the relationship between the oil recovery and the experimental displacement pressure.
According to the experimental results, the recovery of carbon dioxide flooding under different experimental pressures can be obtained (Tab. 2).
The long-slim-tube displacement experiment results of crude oil for injecting CO2.
The generally accepted criterion for miscible flooding is that the oil recovery is greater than 90% when 1.2 PV is injected, and the displacement efficiency does not increase significantly with the increase of displacement pressure [60–63]. In Table 2, the recovery corresponding to the experimental pressure at 20 MPa and 25 MPa is lower than 90%, so the carbon dioxide flooding under these pressures is in the immiscible flooding stage, and the recovery corresponding to the experimental pressure above 30 MPa is higher than 90%, so the carbon dioxide flooding with the pressure above 30 MPa can form miscible flooding. According to the experimental results in Table 2, the relation curve between the oil recovery and the experimental displacement pressure when 1.2 PV carbon dioxide is injected is plotted (Fig. 3). It can be seen from the figure that the MMP of the reservoir crude oil and the carbon dioxide system in the research area predicted by the long-slim-tube displacement experiment method is 29.6 MPa.
The relation curve of recovery and displacement pressure.
Experimental material: The crude oil used in the experiment is the simulated crude oil prepared by the surface oil and natural gas in the research area according to the formation conditions and fluid characteristics. The experiment temperature is 108.5 °C. The purity of carbon dioxide gas is 99.9%, and the property of carbon dioxide gas injected into the research area is exactly the same. Citric acid isobutyl ester is prepared from Section 3.2.
Experimental apparatus: The apparatus for this experiment is the same as that for measuring the MMP of crude oil and carbon dioxide by the long-slim-tube method, as shown in Figure 1.
Citric acid isobutyl ester is oil-soluble surfactant, which is insoluble in water, but can be mutually soluble with mineral oil, castor oil, alcohol and other organic solvents. It is non-toxic, tasteless, low volatile, heat and light resistant, bacteria-resistant, non-bacterial, non-irritating, flame retardant and degradable. As environmentally friendly reagent, the oil-soluble surfactant can not only dissolve in crude oil to reduce viscosity, but also dissolve in carbon dioxide to reduce the interfacial tension between crude oil and carbon dioxide, thus reducing the MMP between crude oil and carbon dioxide. The chemical reagent is prepared by the reaction of citric acid and corresponding alcohols under the condition of catalyst. The following is the synthesis process of citric acid isobutyl ester.
Main experimental materials: citric acid, isobutyl alcohol, p-toluene sulfonic acid, anhydrous sodium sulfate, sodium bicarbonate, sodium chloride, and so on.
Main experimental apparatuses: round-bottom flask, upper water separator, reflux condensing tube and separating funnel, and so on.
Adding chemicals: Add excessive citric acid and isobutyl alcohol to the round-bottom flask.
Adding catalyst: Heat the reaction mixture to 95 °C while stirring, add p-toluene sulfonic acid into the mixture after citric acid is dissolved.
Heating: Heat to 110 °C. The water produced is discharged through the manifold. The reaction begins when water is discharged from the condensing tube. The reaction ends when the condensing tube stops discharging water. P-toluene sulfonic acid as a catalyst can be used for a long time. The chemical reaction equation of citric acid and isobutyl alcohol is shown in Figure 4.
The chemical reaction equation of citric acid and isobutyl alcohol.
Filtration: After the reaction is cooled, filter out the catalyst, which can be washed and dried for reuse.
Filter out citric acid: Add saturated sodium bicarbonate solution and saturated sodium chloride solution. The mixture is separated with the separatory funnel when the temperature reduces to 25 °C.
Water removal: The organic layer is filtered with anhydrous sodium sulfate.
Distillation: Heat to 131.2 °C. After isobutyl alcohol is evaporated, we get citric acid isobutyl ester. The citric acid isobutyl ester obtained after distillation is shown in Figure 5.
The citric acid isobutyl ester obtained after distillation.
For the procedure of this experiment, refer to that of measuring the MMP of crude oil and carbon dioxide with the long-slim-tube method. The difference is that citric acid isobutyl ester is injected before injecting CO2 for displacement. The slug sizes of citric acid isobutyl ester are 0.001 PV, 0.002 PV, 0.003 PV, 0.004 PV, respectively. The recoveries under different pressures were measured after citric acid isobutyl ester was injected with different slug sizes. Then the MMP was calculated for different slug sizes, and the optimal slug size was determined according to the relationship between the slug size and the MMP.
The experimental results of the MMP when the injected citric acid isobutyl ester slug size is 0.001 PV are shown in Figure 6.
Relationship diagram between pressure and recovery at 0.001 PV slug size.
The experimental results of the MMP when the injected isobutyl citrate slug size is 0.002 PV are shown in Figure 7.
Relationship diagram between pressure and recovery at 0.002 PV slug size.
The experimental results of the MMP when the injected isobutyl citrate slug size is 0.003 PV are shown in Figure 8.
Relationship diagram between pressure and recovery at 0.003 PV slug size.
The experimental results of the MMP when the injected isobutyl citrate slug size is 0.004 PV are shown in Figure 9.
Relationship diagram between pressure and recovery at 0.004 PV slug size.
As seen from Figures 6 to 9, when citric acid isobutyl ester with slug sizes of 0.001 PV, 0.002 PV, 0.003 PV and 0.004 PV is injected, the MMPs of crude oil and carbon dioxide measured are 27.9 MPa, 25.5 MPa, 23.5 MPa and 23.2 MPa. From this, we can obtain the relationship between the slug size of citric acid isobutyl ester and the MMP (Tab. 3 and Fig. 10).
Relationship diagram between the MMP and the injected slug size of citric acid isobutyl ester.
Relationship chart between the MMP and the slug size of citric acid isobutyl ester.
As seen from Figure 10, the MMP of crude oil and carbon dioxide measured gradually decreases with the increase of the injected slug of citric acid isobutyl ester, but the decrease becomes smaller and smaller. The optimal injected slug size of citric acid isobutyl ester is 0.003 PV. In this case, the MMP measured is 23.5 MPa. Compared with the MMP 29.6 MPa when citric acid isobutyl ester is not injected, the reduction is 6.1 MPa.
The minimum miscibility pressure of crude oil and carbon dioxide system in the research area determined by the long-slim-tube displacement experiment is 29.6 MPa. The MMP measured schemes for injection of citric acid isobutyl ester with different slug sizes are established and completed. The experimental results show that with the increase of the injected slug size of citric acid isobutyl ester, the measured MMP gradually decreases, but the decrease becomes smaller and smaller. The optimal size of the injected slug is 0.003 PV. Under the condition of the slug size, the MMP measured after the addition of citric acid isobutyl ester slug is 23.5 MPa, which decreases by 6.1 MPa compared with 29.6 MPa when the slug is not injected. The injection of citric acid isobutyl ester slug can significantly reduce the MMP.
There are no conflicts of interest to declare.
This work was financially supported by the National Natural Science Foundation of China (42002154, 51834005), the Natural Science Foundation of Heilongjiang Province (E2016008, QC2016055), the PetroChina Innovation Foundation (2020D-5007-0213), the Youths Science Foundation of Northeast Petroleum University (2019QNL-15) and Open Fund Project of Heilongjiang Key Laboratory of Oil and Gas Reservoir Formation Mechanism and Resource Evaluation (KL20190101). The authors would like to thank the editor and the reviewers of this paper for their valuable comments that helped improve the quality of the paper.
- Azizkhani A., Gandomkar A. (2020) A novel method for application of nanoparticles as direct asphaltene inhibitors during miscible CO2 injection, J. Petrol. Sci. Eng. 185, 106661. https://doi.org/10.1016/j.petrol.2019.106661. [Google Scholar]
- Mogensen K. (2016) A novel protocol for estimation of minimum miscibility pressure from slimtube experiments, J. Petrol. Sci. Eng. 146, 545–551. https://doi.org/10.1016/j.petrol.2016.07.013. [Google Scholar]
- Oschatz M., Antonietti M. (2018) A search for selectivity to enable CO2 capture with porous adsorbents, Energy Environ. Sci. 11, 57–70. [Google Scholar]
- Zhou N., Khanna N., Feng W. (2018) Scenarios of energy efficiency and CO2 emissions reduction potential in the buildings sector in China to year 2050, Nat. Energy 3, 978–984. [Google Scholar]
- Kolster C., Masnadi M.S., Krevor S., Dowell N.M., Brandt A.R. (2017) CO2 enhanced oil recovery: A catalyst for gigatonne-scale carbon capture and storage deployment? Energy Environ. Sci. 10, 2594–2608. [Google Scholar]
- Jalilov A.S., Li Y., Kittrell C. (2017) Increased CO2 selectivity of asphalt-derived porous carbon through introduction of water into pore space, Nat. Energy 2, 932–938. [Google Scholar]
- Chen G.Y., Gao H.X., Fu K.Y., Zhang H.Y., Liang Zh.W., Tontiwachwuthikul A. (2020) An improved correlation to determine minimum miscibility pressure of CO2–oil system, Green Energy Environ. 5, 97–104. [Google Scholar]
- Xing W., Liu Ch., Zhou Z.Y., Zhang L., Zhou J., Zhuo Sh.P., Yan Z.F., Gao H., Wang G.Q., Qiao Sh.Zh. (2012) Superior CO2 uptake of N-doped activated carbon through hydrogen-bonding interaction, Energy Environ. Sci. 5, 7323–7327. [Google Scholar]
- Birdja Y.Y., Pérez-Gallent E., Figueiredo M.C. (2019) Advances and challenges in understanding the electrocatalytic conversion of carbon dioxide to fuels, Nat. Energy 4, 732–745. [Google Scholar]
- Ahmadi M.A., Zendehboudi S., James L.A. (2017) A reliable strategy to calculate minimum miscibility pressure of CO2-oil system in miscible gas flooding processes, Fuel 208, 117–126. [Google Scholar]
- Zhang A.G., Fan Z.F., Zhao L. (2020) An investigation on phase behaviors and displacement mechanisms of gas injection in gas condensate reservoir, Fuel 268, 117373. https://doi.org/10.1016/j.fuel.2020.117373. [Google Scholar]
- Mutailipu M., Jiang L.L., Liu X.J., Liu Y., Zhao J.F. (2019) CO2 and alkane minimum miscible pressure estimation by the extrapolation of interfacial tension, Fluid Phase Equilibr. 494, 103–114. [Google Scholar]
- Gong H.J., Qin X.J., Shang Sh.X., Zhu Ch.F., Xu L., San Q., Li Y.J., Dong M.Zh. (2020) Enhanced shale oil recovery by the Huff and Puff Method using CO2 and cosolvent mixed fluids, Energy Fuels 34, 1438–1446. [Google Scholar]
- Ghorbani M., Gandomkar A., Montazeri G. (2019) Describing a strategy to estimate the CO2-heavy oil minimum miscibility pressure based on the experimental methods, Energ. Source. Part A 41, 17, 2083–2093. [Google Scholar]
- Yu H.Y., Lu X., Fu W.R., Wang Y.Q., Xu H., Xie Q.Ch., Qu X.F., Lu J. (2020) Determination of minimum near miscible pressure region during CO2 and associated gas injection for tight oil reservoir in Ordos Basin, China, Fuel 263, 116737. https://doi.org/10.1016/j.fuel.2019.116737. [Google Scholar]
- Wu Sh.Y., Li Zh.M., Sarma H.K. (2020) Influence of confinement effect on recovery mechanisms of CO2–enhanced tight-oil recovery process considering critical properties shift, capillarity and adsorption, Fuel 262, 116569. https://doi.org/10.1016/j.fuel.2019.116569. [Google Scholar]
- Shao Y., Luo Ch., Deng B.W., Yin B., Yang M.B. (2020) Flexible porous silicone rubber-nanofiber nanocomposites generated by supercritical carbon dioxide foaming for harvesting mechanical energy, Nano Energy 67, 104290. https://doi.org/10.1016/j.nanoen.2019.104290. [Google Scholar]
- Koornneef J., Ramírez A., Turkenburg W., Faaij A. (2012) The environmental impact and risk assessment of CO2 capture, transport and storage – An evaluation of the knowledge base, Progr. Energy Combust. Sci. 38, 62–86. [Google Scholar]
- Kaufmann R.K., Connelly C. (2020) Oil price regimes and their role in price diversions from market fundamentals, Nat. Energy 5, 141–149. https://doi.org/10.1038/s41560-020-0549-1. [Google Scholar]
- Zhang J., Zhang H.X., Ma L.Y., Liu Y., Zhang L. (2020) Performance evaluation and mechanism with different CO2 flooding modes in tight oil reservoir with fractures, J. Petrol. Sci. Eng. 188, 106950. https://doi.org/10.1016/j.petrol.2020.106950. [Google Scholar]
- Yang Z.H., Wu W., Dong Zh.X., Lin M.Q., Zhang Sh.W., Zhang J. (2019) Reducing the minimum miscibility pressure of CO2 and crude oil using alcohols, Colloids Surf. A Physicochem. Eng. Aspects 568, 105–112. [Google Scholar]
- Torabi F., Qazvini F.A., Kavousi A. (2012) Comparative evaluation of immiscible, near miscible and miscible CO2 huff-n-puff to enhance oil recovery from a single matrix-fracture system (experimental and simulation studies), Fuel 93, 4, 443–453. [Google Scholar]
- Guo P., Hu Y.Sh., Qin J.Sh., Li Sh., Jiao S.J., Chen F., He J. (2017) Use of oil-soluble surfactant to reduce minimum miscibility pressure, Petrol. Sci. Technol. 35, 4, 345–350. [Google Scholar]
- Ju B.Sh., Qin J.Sh., Li Zh.P. (2012) A prediction model for the minimum miscibility pressure of the CO2-crude oil system, Acta Petrolei Sinica 33, 2, 274–277. [Google Scholar]
- Qin J.Sh., Han H.Sh., Liu X.L. (2015) Application and enlightenment of carbon dioxide flooding in the United States of America, Petrol. Explor. Dev. 42, 2, 209–216. [Google Scholar]
- Hawthorne B.S., Miller D.J., Gorecki C.D. (2014) A rapid method for determining CO2/oil MMP and visual observations of CO2/oil interactions at reservoir conditions, Energy Proc. 63, 7724–7731. [Google Scholar]
- Ma M., Liu K., Shen J., Kas R., Smith W.A. (2018) In Situ fabrication and reactivation of highly selective and stable Ag catalysts for electrochemical CO2 conversion, ACS Energy Lett. 3, 1301–1306. [Google Scholar]
- Moghaddam A.K., Dehaghani A.H.S. (2017) Modeling of asphaltene precipitation in calculation of minimum miscibility pressure, Ind. Eng. Chem. Res. 56, 7375–7383. [Google Scholar]
- Jaubert J.N., Avaullee L., Pierre C. (2002) Is it still necessary to measure the minimum miscibility pressure? Indus. Eng. Chem. Res. 41, 2, 303–310. [Google Scholar]
- Avaullée L., Duchet-Suchaux P., Durandeau M., Jaubert J.N. (2001) A new approach in correlating the oil thermodynamic properties, J. Petrol. Sci. Eng. 30, 1, 43–65. [Google Scholar]
- Wu Sh., He J., Li Z.Zh., Lin W.M., Wang Q.T., Wu F.Y., Zhao B., Zhang J.J. (2015) Studies on the chemical agent system for reducing in the minimal miscibility pressure of CO2 flooding, China Sciencepaper 10, 18, 2161–2164. [Google Scholar]
- Jing L.Sh. (2014) Solubility of nonionic surfactants used in CO2 miscible flooding, Master Thesis, Dalian University of Technology. [Google Scholar]
- Guo P., Jiao S.J., Chen F., He J., Li Y.Q., Zeng H. (2012) Optimization and oil displacement efficiency of non-ionic low molecular surfactant, Oil Drill. Prod. Technol. 34, 2, 81–84. [Google Scholar]
- Zhang G.D., Liu J.Y., Liu Y.L., Zhou F. (2013) Study on reducing miscibility pressure in CO2 flooding by miscible solvent, Special Oil Gas Reserv. 20, 2, 115–117. [Google Scholar]
- Peng Ch., Liu J.Y., Zhang G.D., Peng Y.J., Guo K. (2012) A new method of reducing the miscible-phase pressure of CO2 flooding, Journal of Chongqing University of Science and Technology (Natural Science edition) 14, 1, 48–51. [Google Scholar]
- Harrison K., Goveas J., Johnston K.P., O’Rear E.A. (1994) Water-in-carbon dioxide microemulsions with a fluorocarbon-hydrocarbon hybrid surfactant, Langmuir 10, 10, 3536–3541. [Google Scholar]
- Eastoe J., Gold S. (2005) Self-assembly in green solvents, Phys. Chem. Chem. Phys. 7, 7, 1352–1362. [Google Scholar]
- Rocha S.R.P.D., Dickson J., Cho D., Rossky P.J., Johnston K.P. (2003) Stubby surfactants for stabilization of water and CO2 emulsions: trisiloxanes, Langmuir 19, 8, 3114–3120. [Google Scholar]
- Fink R., Hancu D., Valentine R., Beckman E.J. (1999) Toward the development of “CO2-philic” hydrocarbons. 1. Use of side-chain functionalization to lower the miscibility pressure of polydimethylsiloxanes in CO2, J. Phys. Chem. B 103, 31, 6441–6444. [Google Scholar]
- Zhang T.Y., Zhong L. (2005) Surfactants for supercritical CO2, Chem. Bull. 68, 8, 585–590. [Google Scholar]
- Hoefling T., Stofesky D., Reid M., Beckman E., Enick R.M. (1992) The incorporation of a fluorinated ether functionality into a polymer or surfactant to enhance CO2-solubility, J. Supercrit. Fluids 5, 4, 237–241. [Google Scholar]
- DeSimone J.M., Keiper J.S. (2001) Surfactants and self-assembly in carbon dioxide, Curr. Opin. Solid State Mater. Sci. 5, 4, 333–341. [Google Scholar]
- Lou D.L., Xu B.Ch., Qiu T.Q. (2013, 1861) Comparison and dynamic models of supercritical CO2 extraction enhanced by different technologies, Modern Food Sci. Technol. 29, 8, 1921–1925. [Google Scholar]
- Dong Zh.X., Cui B., Li Y., Lin M.Q., Li M.Y. (2013) MMP of supercritical carbon dioxide microemulsion and alkanes, J. Petrochem. Univ. 26, 1, 40–44. [Google Scholar]
- Dong Zh.X., Li Y., Lin M.Q., Li M.Y. (2013) A study of the mechanism of enhancing oil recovery using supercritical carbon dioxide microemulsions, Petrol. Sci. 10, 1, 91–96. [Google Scholar]
- Song Zh.J., Li Zh.P., Yu Ch.Sh. (2014) D-optimal design for rapid assessment model of CO2 flooding in high water cut oil reservoirs, J. Nat. Gas Sci. Eng. 21, 11, 764–771. [Google Scholar]
- Han H.Sh., Li Sh., Chen X.L. (2016) Main control factors of carbon dioxide on swelling effect of crude hydrocarbon components, Acta Petrolei Sinica 37, 3, 392–398. [Google Scholar]
- Yang Zh.M., Liu X.W., Zhang Zh.H. (2015) Physical simulation of staged-fracturing horizontal wells using CO2 huff and puff in tight oil reservoirs, Acta Petrolei Sinica 36, 6, 724–729. [Google Scholar]
- Chen F., He J., Guo P. (2012) A method used for reducing the minimum miscible pressure between oil and CO2 in miscible flooding, Chinese Patent 102337874A 2. [Google Scholar]
- Choubineh A., Mousavi S.R., Ayouri M.V., Ahmadinia M., Choubineh D., Baghban A. (2016) Estimation of the CO2-oil minimum miscibility pressure for enhanced oil recovery, Petrol. Sci. Technol. 34, 22, 1847–1854. [Google Scholar]
- Li D., Li X.L., Zhang Y.H., Sun L.X., Yuan Sh.L. (2019) Four methods to estimate minimum miscibility pressure of CO2-oil based on machine learning, Chin. J. Chem. 37, 1271–1278. [Google Scholar]
- Ebrahimi A., Khamehchi E. (2014) The use of optimization procedures to estimate minimum miscibility pressure, Petrol. Sci. Technol. 32, 8, 947–957. [Google Scholar]
- Rahimi V., Bidarigh M., Bahrami P. (2017) Experimental study and performance investigation of miscible water-alternating-CO2 flooding for enhancing oil recovery in the Sarvak formation, Oil Gas Sci. Technol. - Rev. IFP Energies nouvelles 72, 35. https://doi.org/10.2516/ogst/2017030. [Google Scholar]
- Luo E.H., Fan Z.F., Hu Y.L., Zhao L., Wang J.J. (2019) An evaluation on mechanisms of miscibility development in acid gas injection for volatile oil reservoirs, Oil Gas Sci. Technol. - Rev. IFP Energies nouvelles 74, 59. https://doi.org/10.2516/ogst/2019018. [Google Scholar]
- Jaubert J.N., Borg P., Coniglio L., Barth D. (2001) Phase equilibria measurements and modeling of EPA and DHA ethyl esters in supercritical carbon dioxide, J. Supercrit. Fluids 20, 2, 145–155. https://doi.org/10.1016/S0896-8446(01)00062-6. [Google Scholar]
- Jaubert J.N., Coniglio L., Denet F. (1999) From the Correlation of Binary Systems Involving Supercritical CO2 and Fatty Acid Esters to the Prediction of (CO2−Fish Oils) Phase Behavior, Indus. Eng. Chem. Res. 38, 8, 3162–3171. https://doi.org/10.1021/ie980783l. [Google Scholar]
- Delforouz F.B., Movaghar M.R.K., Shariaty S. (2019) New empirical correlations for predicting Minimum Miscibility Pressure (MMP) during CO2 injection; implementing the Group Method of Data Handling (GMDH) algorithm and Pitzer’s acentric factor, Oil Gas Sci. Technol. - Rev. IFP Energies nouvelles 74, 64. https://doi.org/10.2516/ogst/2019035. [Google Scholar]
- Abdurrahman M., Bae W., Permadi A.K. (2019) Determination and evaluation of minimum miscibility pressure using various methods: experimental, visual observation, and simulation, Oil Gas Sci. Technol. - Rev. IFP Energies nouvelles 74, 55. https://doi.org/10.2516/ogst/2019028 [Google Scholar]
- Nichita D.V., Broseta D., Montel F. (2019) Application of near critical behavior of equilibrium ratios to phase equilibrium calculations, Oil Gas Sci. Technol. - Rev. IFP Energies nouvelles 74, 77. https://doi.org/10.2516/ogst/2019049. [Google Scholar]
- Berneti S.M., Varaki M.A. (2018) Development of ε-insensitive smooth support vector regression for predicting minimum miscibility pressure in CO2 flooding, Songklanakarin J. Sci. Technol. 40, 1, 53–59. [Google Scholar]
- Zhang A.G., Fan Z.F., Zhao L., Xu A.Zh. (2020) An evaluation on phase behaviors of gas condensate reservoir in cyclic gas injection, Oil Gas Sci. Technol. - Rev. IFP Energies nouvelles 75, 4. https://doi.org/10.2516/ogst/2019070. [Google Scholar]
- He C.G., Mu L.X., Xu A.Zh., Zhao L., He J., Zhang A.G., Shan F.Ch., Luo E.H. (2019) Phase behavior and miscible mechanism in the displacement of crude oil with associated sour gas, Oil & Gas Science and Technology - Rev. IFP Energies nouvelles 74, 54. https://doi.org/10.2516/ogst/2019024. [Google Scholar]
- Fathinasab M., Ayatollahi S., Taghikhani V., Shokouh S.P. (2018) Minimum miscibility pressure and interfacial tension measurements for N2 and CO2 gases in contact with W/O emulsions for different temperatures and pressures, Fuel 225, 623–631. https://doi.org/10.1016/j.fuel.2018.03.134. [Google Scholar]