Abstract

This work reports saturated-phase densities for the CO2 + methylcyclohexane system at temperatures between 298 and 448 K and at pressures up to the critical pressure. The densities were measured with a standard uncertainty of <1.5 kg·m–3 and were fitted along isotherms with a recently developed nonlinear empirical correlation with an absolute average deviation (ΔAAD) of about 1.5 kg·m–3. This empirical correlation also allowed the estimation of the critical pressure and density at each temperature, and the obtained critical pressures were found to be in close agreement with previously published data. We also compare both our density data and vapor–liquid equilibrium (VLE) data from the literature with the predictions from two models: PPR-78 and SAFT-γ Mie. The results show that densities were predicted better with SAFT-γ Mie than with PPR-78, whereas PPR-78 generally performed better for VLE. This could indicate that some of the unlike parameters of SAFT-γ Mie could be further optimized.

Highlights

  • Mixtures of carbon dioxide and hydrocarbons are involved in many industrial applications such as supercritical extraction,[1] separation processes,[2,3] gas hydrates applications,[4] and carbon capture and storage (CCS).[5]

  • Experimental saturated-phase densities for the (CO2 + methylcyclohexane) system are reported over an extended temperature range with pressures up to the critical

  • Except for a few measurements in the critical region, the estimated standard uncertainty is less than 1.5 kg·m−3

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Summary

Introduction

Mixtures of carbon dioxide and hydrocarbons are involved in many industrial applications such as supercritical extraction,[1] separation processes,[2,3] gas hydrates applications,[4] and carbon capture and storage (CCS).[5] The thermophysical properties of (CO2 + hydrocarbon) systems over wide ranges of pressures and temperatures are necessary to design and optimize the aforementioned processes.[6] For instance, in CCS, the CO2 storage capacity on an oil reservoir is affected, in part, by the density and phase behavior of such mixtures. Convective flows within the reservoir depend upon the density difference between the vapor and liquid phases.[7] thermodynamic models employed in the simulation process must be evaluated against reliable experimental data to achieve the optimal design and operation of the industrial application. The PPR-78 model was successfully used to describe the fluid phase behavior of mixtures that contained paraffin, naphthenes, aromatics, and CO2.11,12 Another group-contribution approach is the SAFT-γ

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