High pressure density and solubility for the CO2 + 1-ethyl-3-methylimidazolium ethylsulfate system

Densities and viscosities of binary mixtures of {dimethylsulfoxide + aliphatic lower alkanols (C 1–C 3)} at temperatures from T = 303.15 K to T = 323.15 K

In the immiscible displacement of oil by carbon dioxide gas, the solubility and diffusivity of carbon dioxide are important factors that determine the efficiency of the process, because an increase in the carbon dioxide solubility and diffusivity into oil leads to an increase in oil recovery. It is shown by experimental studies that the solubility and diffusivity of carbon dioxide into oil are governed by the saturation pressure, reservoir temperature, composition of the oil and purity of the gas. The solubility and diffusivity of carbon dioxide into Aberfeldy heavy oil were measured, using impure carbon dioxide gas containing nitrogen as the main contaminant gas. It was noted that increasing the concentration of nitrogen in the carbon dioxide stream decreased the solubility and diffusivity of carbon dioxide in oil, consequently leading to a reduction in the swelling of the oil by carbon dioxide. Displacement experiments were also conducted to observe the effect of using impure carbon dioxide in place of pure carbon dioxide in the immiscible displacement WAG process. It was noted that the presence of nitrogen in carbon dioxide adversely affected oil recovery by the process and that increasing the nitrogen concentration up to 30 mole% could result in 10% loss in oil recovery. Introduction The solubility of carbon dioxide is the most important effect in the immiscible displacement of oil by carbon dioxide gas since it was found by Rojas(1) that among other mechanisms, an increase in the carbon dioxide solubility in oil leads to an increase in oil recovery. This is true because the solubility of carbon dioxide greatly reduces the viscosity of the oil and promotes the swelling of the oil. Viscosity reduction and swelling of the oil lower the water-oil mobility ratio, consequently leading to an increased oil recovery. Early work in 1926 by Beecher and Parkhurst(2) showed that carbon dioxide was more soluble on a molar basis in a 30.2 °API oil than air and natural gas. Svreck and Mehrota's data(3) for carbon dioxide, methane and nitrogen showed that and Mehrotra's data(3), carbon dioxide is the most soluble and nitrogen the least soluble in bitumen. The solubility of carbon dioxide in oil is governed by the saturation pressure, reservoir temperature, composition of the oil and purity of the gas. Miller and Jones(4) and Chung, Jones, and Nguyen(5) measured the solubility of carbon dioxide in Canyon and Wilmington heavy oils and found that the solubility of carbon dioxide in heavy crude oils increased with pressure but decreased with temperature and reduced API gravity. Briggs and Puttagunta(6) reported sets of data for carbon dioxide solubility in Aberfeldy oil and swelling of oil at 20.6 °C. Their data showed that both carbon dioxide solubility and oil swelling increased when pressure increased. Later, Sayegh and Sarbar(7) established that carbon dioxide is more soluble in oil at lower temperatures than at higher ones.

Effect of Nitrogen On the Solubility And Diffusivity of Carbon Dioxide Into Oil And Oil Recovery By the Immiscible WAG Process T.A. Nguyen; T.A. Nguyen Petroleum Recovery Institute Search for other works by this author on: This Site Google Scholar S.M. Farouq Ali S.M. Farouq Ali Petroleum Recovery Institute Search for other works by this author on: This Site Google Scholar Paper presented at the Annual Technical Meeting, Calgary, Alberta, June 1995. Paper Number: PETSOC-95-64 https://doi.org/10.2118/95-64 Published: June 06 1995 Cite View This Citation Add to Citation Manager Share Icon Share Facebook Twitter LinkedIn Email Get Permissions Search Site Citation Nguyen, T.A., and S.M. Farouq Ali. "Effect of Nitrogen On the Solubility And Diffusivity of Carbon Dioxide Into Oil And Oil Recovery By the Immiscible WAG Process." Paper presented at the Annual Technical Meeting, Calgary, Alberta, June 1995. doi: https://doi.org/10.2118/95-64 Download citation file: Ris (Zotero) Reference Manager EasyBib Bookends Mendeley Papers EndNote RefWorks BibTex Search nav search search input Search input auto suggest search filter All ContentAll ProceedingsPetroleum Society of CanadaPETSOC Annual Technical Meeting Search Advanced Search AbstractIn the immiscible displacement of oil by carbon dioxide gas, the solution and diffusion of carbon dioxide are important factors that determine the efficiency of the process, since an increase in the carbon dioxide solubility and diffusivity into oil leads to an increase in oil recovery because the oil phase left behind contains more carbon dioxide and less oil. It is shown by experimental studies that the solubility and diffusivity of carbon dioxide into oil are governed by the saturation pressure, reservoir temperature I composition of the oil and purity of the gas. The solubility and diffusivity of carbon dioxide into Aberfeldy heavy oil were measured, using impure carbon dioxide gas containing nitrogen as the main ontaminant gas. It was noted that increasing the concentration of nitrogen in the carbon dioxide stream ecreased the solubility and. diffusivity of carbon dioxide into oil, consequently leading to a reduction in the swelling oil of by carbon dioxide.Displacement experiments were also conducted to observe the effect of using impure carbon dioxide in place of pure carbon dioxide in the immiscible displacement WAG process. It was noted that the presence of nitrogen in carbon dioxide adversely affected oil recovery by the process and that increasing the nitrogen concentration up to 30 mole% could result in 10% loss in oil recovery.IntroductionThe solubility of carbon dioxide is the most important effect in the immiscible displacement of oil by carbon dioxide gas since it is theorized that among other mechanisms, an increase in the carbon dioxide solubility in oil leads to an increase in oil recovery because the oil phase left behind contains more carbon dioxide and less oil.Early work in 1926 by Beecher and Parkhurst1 showed that carbon dioxide was more soluble on a molar basis in a 30.2 °API oil than air and natural gas. Svreck and Mehrotra's data2 also showed that, among the three gases: carbon dioxide methane, and nitrogen, carbon dioxide is the most soluble and nitrogen the least soluble in bitumen.The solubility of carbon dioxide in oil is governed by the saturation pressure, reservoir temperature, composition of the oil and purity of the gas. Miller and Jones3 and Chung, Jones, and Nguyen4 measured the solubility of carbon dioxide n Canyon and Wilmington heavy oils and found that the solubility of carbon dioxide in heavy crude oils increased with pressure but decreased with temperature and reduced API gravity. Later, Sayegh and Sarbar5 established that carbon dioxide is more soluble in oil at lower temperatures than at higher ones. Patton, Coats, and Spence6, Holm and Josendal7, and Chung et al4 showed that the solubility of carbon dioxide reduced with me presence of methane in oil since carbon dioxide had to displace methane before dissolving in oil Holm and Josendal7 also mentioned that carbon dioxide did not displace all of the methane when it came into contact with oil. Spivak and Chima noted that the solubility of pure carbon dioxide in oil was higher than that of a carbon dioxide-nitrogen mixture. Keywords: upstream oil & gas, dioxide, petroleum society, experiment, oil recovery, pvt measurement, carbon dioxide, carbon dioxide solubility, nitrogen, carbon dioride Subjects: Fluid Characterization, Improved and Enhanced Recovery, Phase behavior and PVT measurements This content is only available via PDF. 1995. Petroleum Society of Canada You can access this article if you purchase or spend a download.

Phase equilibria of essential oil components and supercritical carbon dioxide

Densities and viscosities of binary mixtures of N,N-dimethylformamide (DMF) with aniline and benzonitrile have been measured at (298.15, 303.15, 308.15, and 313.15) K. From these data, excess molar volumes (VE) and deviations in viscosity (Δη) have been calculated. Negative excess molar volumes and negative deviations in viscosity for DMF + aniline systems are attributed to the interstitial accommodation of DMF molecules into clusters of aniline. Negative excess molar volumes and positive deviations in viscosity for DMF + benzonitrile systems are due to the strong specific interactions. The excess molar volumes and deviations in viscosity are fitted to the Redlich−Kister polynomial equation.

Excess molar volumes (V E) and deviation in isentropic compressibilities (Δβ s) have been investigated from the density ρ and speed of sound u measurements of six binary liquid mixtures containing n-alkanes over the entire range of composition at 298.15 K. Excess molar volume exhibits inversion in sign in one binary mixture, i.e., n-heptane + n-hexane. Remaining five binary mixtures, n-heptane + toluene, cyclohexane + n-heptane, cyclohexane + n-hexane, toluene + n-hexane and n-decane + n-hexane show negative excess molar volumes over the whole composition range. However, the large negative values of excess molar volume becomes domainant in toluene + n-hexane mixture. Deviation in isentropic compressibility is negative over the whole range of composition in the case of all the six binary mixtures. Existence of specific intermolecular interactions in the mixtures has been analyzed in terms of excess molar volume and deviation in isentropic compressibility.

Volumetric properties of ethyl acetate + carbon dioxide binary fluid mixtures at high pressures

Densities of the systems, 1-Propanol(P)+aniline(A), 1-Propanol(P)+N-Methylaniline (NMA) and 1-Propanol(P)+N,N-Dimethylaniline(DMA) have been measured from 21°C to 50°C at an interval of 5°C. The excess molar volumes, V E, of the systems, P+A and P +NMA have been found to be negative for the whole range of composition. VE of the system P+DMA has also been found to be negative, except in DMA-rich region where small positive excess volume is observed. The negative excess volume has been explained primarily in terms of strong specific interaction and size difference of unlike molecules. The magnitude of the negative excess volumes of these systems is of the order, P+A > P + NMA > P + DMA, which has been strongly influenced by steric effect due to CH3 group attached to N-atom of NMA and DMA. In the highly rich region of DMA in P+DMA system the small positive excess volume is accounted for by the steric effect and breaking up of H-bond of 1-Propanol.

Densities and viscosities for three binary systems, cyclohexane + toluene, cyclohexane + decalin, and toluene + decalin, at T = (283.15, 293.15, 303.15, 313.15, and 323.15) K have been measured over the whole composition range and atmospheric pressure along with the properties of the pure components. Viscosities deviations and excess molar volumes for the binary systems at the above-mentioned temperatures were calculated from experimental data and fitted to the Redlich−Kister expansion. In addition, the Prigogine−Flory−Patterson (PFP) model was used to correlate experimental density data. The Redlich−Kister expansion well correlated viscosity deviation and excess volume values. Shape and length asymmetries and molecular interaction asymmetries impact on viscosity deviations, but the latter had a more pronounced influence. Negative excess molar volumes were found when only shape and length asymmetries were present, while molecular interaction asymmetries led to positive values. The effects of simultaneous ...

In this work, the solubility of carbon dioxide, CO2, in pentaerythritol tetrapentanoate (PEC5) and in pentaerythritol tetra(2-ethylhexanoate) (PEBE8) has been performed from (283 to 333) K and pressures up to 7 MPa in a new high-pressure gas solubility apparatus. The results show that in the present analyzed range CO2 is highly soluble in these oils and that the solubility expressed as CO2 mole fraction is practically not dependent on the branching of the acid chain, whereas it increases slightly with the length of the PE acid chains in the present range of compositions. The gas solubility data were satisfactorily correlated with the Soave−Redlich−Kwong (SRK) equation of state (EOS) using the conventional quadratic mixing rule with two interaction parameters for each temperature.

Solubility of carbon dioxide in pentaerythritol ester oils. New data and modeling using the PC-SAFT model

The immiscible carbon dioxide flooding process has considerable potential for the recovery of moderately viscous oils, which are unsuited for the application of thermal recovery techniques. Approximately 95% of Saskatchewan's heavy oil formations are less than 10m thick, and often have an underlying water sand. Under these conditions, thermal methods are inefficient and uneconomical due to excessive vertical heat loss and steam scavenging by the bottom water. This provides the motivation for searching an alternative to thermal recovery techniques for thin, moderately heavy oils. Laboratory research conducted in the 1950s identified several aspects of carbon dioxide flooding such as viscosity reduction, oil swelling, miscibility effects, and solution gas drive. Both laboratory and field studies have been conducted to determine the effectiveness of the carbon dioxide process for heavy oil recovery. This paper concentrates on the laboratory and field studies conducted in the past as well as the future of the immiscible carbon dioxide flooding process for the recovery of heavy oils. Introduction Moderately viscous heavy oils lack the necessary extractable hydrocarbons [C5 - C30 ] for miscible conditions with carbon dioxide to be economically attained. In some cases, moderately light oils [25–35 °API] are displaced immiscibly because the high pressures required to achieve miscibility with carbon dioxide would lead to formation fracturing. This is undesirable in that it leads to gas channeling and early carbon dioxide breakthrough. Both laboratory and field studies have been conducted to determine the effectiveness of the immiscible carbon dioxide process. Laboratory studies are used to determine and optimize the recovery process mechanisms. Field studies, both pilot and conventional, have been conducted in two modes, namely: primary and tertiary. Primary recovery methods have been the most successful to date while tertiary methods have helped greatly in reducing water and gas cuts in late flood life projects1. The objectives of this paper are to give a resume of the dominant mechanisms in the immiscible carbon dioxide displacement process, and to analyze field data in order to develop the minimum criteria for process selection. Transport of Carbon Dioxide in Heavy Oil and Reservoir Water How does the carbon dioxide mix with the reservoir fluids, namely: oil and water? Three mass transfer mechanisms are discussed in this section. Solubility is the most important mechanism of carbon dioxide transport in the reservoir. Diffusion and dispersion also affect, to a lesser extent, the transport of carbon dioxide. The most important property of heavy oil-carbon dioxide, systems is carbon dioxide solubility. "Solubility of one substance in another depends fundamentally upon the ease with which the two: molecular species are able to mix. 2 Klins3 stated: that for low pressure application [<7 MPa), the major effect would be the solubility of carbon dioxide in crude oil. The solubility of pure carbon dioxide in Lloydminster Aberfeldy 115-l7 °API] oil at 5.5 MPa and 20.6 °C is approximately 70 sm3/sm3 of oil. Solubility is a strong function of pressure, and to a lesser degree, temperature and oil composition. Solubility increases with pressure and decreases with temperature and reduced API gravity.

It is important to evaluate the solubility of solid carbon dioxide in liquefied natural gas for natural gas liquefaction at relatively high temperature. The regular solution method and the equations-of-state (EOS) are used to calculate the solubility of carbon dioxide in saturated liquid methane in this paper. The calculation results are compared with the experiment data, and it certifies that the EOS method can be recommended for this kind of solubility calculation. In addition, nitrogen and ethane are common components in natural gas. In this paper, PR EOS is selected to calculate the solubility of carbon dioxide in CH4+N2 and CH4+C2H6 mixtures. Results show that the solubility of carbon dioxide in liquid CH4+N2 mixtures increases with the addition of nitrogen content in the relatively low temperature region (lower than 155K). With the temperature increases, the solubility of carbon dioxide decreases with the increase of nitrogen content. While in liquid CH4+C2H6 mixtures, it increases with the increase of ethane content. liquid nitrogen, liquid oxygen or LNG. In 1940, Fedorova calculated the solubility of carbon dioxide in liquid oxygen and in liquid nitrogen according to ideal solution theory. At the same time, he did some experiments and found that the theoretical calculations are more than 100 times larger than the experimental values(7). In 1962, Davis et al performed a series of experiments on the methane-carbon dioxide system and got the solubility of carbon dioxide in methane at different temperatures(8). Most of these researchers are experts in the field of chemistry, who were focus on a variety of experimental methods of solubility determination. Li from Zhejiang University used the regular solution method and modified Scatchard-Hildebrand relation in her PhD thesis to calculate the solubility of carbon dioxide in liquid nitrogen and liquid oxygen, and obtained good results(9). As liquid methane is a cryogenic non-polar liquid similar with liquid nitrogen and liquid oxygen, similar method has been imitated in the calculation of the solubility of carbon dioxide in the saturated liquid methane in this paper. Additionally, simple cubic equations-of-state has been widely used in non-polar fluid phase equilibria calculations. In 2006, ZareNezhad and Eggeman(10) used PR EOS to predict CO2 freezing points of hydrocarbon liquid and vapor mixtures at cryogenic conditions of gas plants. The overall average absolute relative deviation between the experimental and predicted CO2 freezing temperatures for this binary system is 0.26%. So EOS method is selected for the solid-liquid phase equilibria calculation in this paper.

The solubility of pure carbon dioxide in Athabasca bitumen was measured and compared with the literature data. Multiple liquid phases were observed at carbon dioxide contents above approximately 12 wt%. A correlation based on Henry's law was found to fit the saturation pressures at carbon dioxide contents below 12 wt%. The saturation pressure and solubility of carbon dioxide and propane in Athabasca bitumen, as well as the liquid phase densities and viscosities, were measured for three ternary mixtures at temperatures from 10 to 25 °C. Two liquid phases (carbon dioxide-rich and bitumen-rich) were observed at 13 wt% carbon dioxide and 19 wt% propane. Only liquid and vapour-liquid regions were observed for the other two mixtures (13.5 wt% propane and 11.0 wt% carbon dioxide; 24.0 wt% propane and 6.2 wt% carbon dioxide). The saturation pressures for the latter mixtures were predicted using the correlation for the carbon dioxide partial pressure and a previously developed correlation for the propane partial pressure. The mixture viscosities were predicted with the Lobe mixing rule. Introduction In Part I of this work(1), mixtures of carbon dioxide and propane were identified as a potential solvent for the VAPEX process. At typical heavy oil reservoir conditions (pressure of ~1.2 MPa and temperature of ~10 °C), propane and butane have sufficient solubility to reduce the oil viscosity to a level where gravity drainage can occur in an economic time scale. However, propane and butane are expensive solvents and the success of the process depends on how much solvent can be recovered. As well, the VAPEX process operates below the saturation pressure of the solvent and, therefore, propane and butane cannot be used at higher reservoir pressures where they exist only in the liquid phase. Methane can be added to achieve the desired pressures(2). However, carbon dioxide may also be a better VAPEX solvent than methane because it is more soluble in heavy oil and significantly reduces the viscosity(3). Mixtures of carbon dioxide and propane may achieve the desired reduction in viscosity while minimizing the required propane volumes. Hence, there is an incentive to evaluate mixtures of carbon dioxide and propane as a VAPEX solvent. VAPEX performance depends on the viscosity and density of the liquid phase that forms at the edge of the vapour chamber. In order to design and optimize VAPEX and other solvent-based processes, it is critical to be able to determine the diffusivity of the solvent in the heavy oil, identify the phases that form in the solvent and heavy oil mixtures at various temperatures and pressures, and determine the density and viscosity of the liquid phase. Other solvent-based processes (steam and solvent injection for heavy oil recovery and solvent extraction of oil sands) require similar data. In Part I of this work(1), saturation pressures and liquid phase densities and viscosities were measured for propane and Athabasca bitumen. There are also considerable data in the literature for mixtures of carbon dioxide and crude oils. Simon and Graue(4) measured the solubility, swelling and viscosity of mixtures of carbon dioxide and nine different oils.

ON account of their extreme molecular simplicity, binary liquid rare gas mixtures are of particular importance for testing theories which seek to calculate the thermodynamic properties of solutions. Quantum effects and the physical properties of the rare gases limit the number of such mixtures which it is possible to study over the whole range of liquid composition to two, namely argon–krypton and krypton–xenon. Even for these two mixtures, at the lowest temperature at which the whole range of composition can be covered, namely the triple-point of the less-volatile component, the vapour pressure of the other component is comparatively high. Thus, the vapour pressure of argon at the krypton triple-point is about 9.4 atm. Partly for this reason, there has not hitherto been a comprehensive investigation of the thermodynamic properties of liquid mixtures of argon and krypton or of krypton and xenon. Vapour pressure measurements have been made of solid solutions in both systems1–3, but investigations of liquid mixtures have hitherto been confined to vapour pressure and liquid and vapour composition measurements for the argon–krypton system at 88.05° K (ref. 4), when the separation of a solid phase limits the mole fraction of krypton in the liquid to a maximum of about 0.35. Similar measurements have also been made at 87.5° K (ref. 5) up to a krypton mole fraction of 0.13.