The viscosity of pure hydrocarbons was correlated using a simple function based on the fluid density. The correlation has three adjustable parameters, a compressed state density, F s °, an empirical parameter, c 2 , that scales the viscosity response to fluid expansion, and another empirical parameter, c 3 , used to tune at pressures above 10 MPa. The inputs to the correlation are the fluid density, pressure, and low-pressure gas viscosity. The correlation fit experimental viscosities for 39 pure hydrocarbons including n-alkanes, branched alkanes, alkenes, cyclics, and aromatics, within experimental error over a broad range of temperatures and pressures. Heavy hydrocarbons such as mineral oils were also fit with an AAPRD of 2.7%. Binary mixture viscosities were predicted to within 10% using simple volumetric mixing rules. The method provides a single framework for liquid and vapor phases, is simple to implement, and is very fast computationally, making it ideal for incorporation into process and reservoir simulators.
The solubility of the major constituents of natural gas in ionic liquids (ILs) can be used to identify their potential for acid gas removal from a producing gas stream. We have developed models for the solubility of H 2 S, CH 4 , and C 2 H 6 in ILs at typical conditions encountered in natural gas treatment. In this work, a conductor-like screening model for realistic solvation was used to predict the activity coefficients for solutes in ILs and a cubic EOS was used for vapor-phase corrections from ideality. Empirical correlations were developed to extrapolate solubilities where experimental data are not available at desired conditions; targeted in this study at 298.15 K and 2000 kPa. Over 400 possible ILs were ranked based on the higher selectivity of absorption of CO 2 and H 2 S over CH 4 and C 2 H 6 . The best 15% (58) of promising ILs for sour gas treatment predominantly contain the anions BF 4 , NO 3 , and CH 3 SO 4 and the cations N 4111 , pmg, and tmg.
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