Abstract
In this study, highly accurate measurements of density and dynamic viscosities of a recombined live oil and its mixture with additional CO2were performed. The experiments were carried out under pressure and temperature gradients found in Brazilian Pre-salt reservoirs, that is, in the pressure range from (27.6 to 68.9) MPa and at (333.15 and 353.15) K. The assumption of volume change on mixing is evaluated from the experimental results, and the influence of pressure and temperature on the volume change upon mixing is assessed. The densities of mixtures are calculated considering (i) the excess volume approach, and (ii) no volume change. The densities are better correlated using the excess volume approach with Average Absolute Deviations (AAD) of 0.03%. Thirteen mixing rules of viscosity are examined by comparing the predicted values with the experimental viscosity of the recombined live oil + CO2mixture. The performance of some rules using compositional fractions (molar, volume and weight) is also evaluated. Thus, a total of 28 different ways to calculate the mixture viscosities were tested in this study. The worst result was obtained with Bingham’s method, leading to 148.6% AAD. The best result was obtained from Lederer’s method with 2% AAD and a maximum deviation of 5.8% using volume fractions and the fitting parameterα. In addition, deviations presented by the predictive methods of Chevron, Double log, and Kendall did not exceed 9% AAD, using weight fractions (Chevron and Double log) and molar fractions (Kendall and Monroe).
Highlights
Enhanced Oil Recovery (EOR) processes demonstrate great potential in recovering trapped oil at the pore scale providing opportunities to recover oils that would not be produced
Oil recovery is predominantly influenced by the capillary number, which characterizes the ratio of viscous forces to surface or interfacial tension forces [8, 9]
The density measurements for the Recombined Live Oil (RLO) and its mixture with additional CO2 were performed along two isotherms, Table 6
Summary
Enhanced Oil Recovery (EOR) processes demonstrate great potential in recovering trapped oil at the pore scale providing opportunities to recover oils that would not be produced. As the injection of CO2 causes changes in crude and gas thermophysical properties and phase equilibria [15,16,17,18,19], it is necessary to recalculate the equilibrium of the CO2-oil system for the CO2 injection scenario as well as assessing the viscosity-pressure behavior It is required additional experimental data of density and viscosity as a function of temperature and pressure of the mixture comprising oil with dissolved CO2. The experiments were carried out in a PVT cell at temperatures and a pressure range representative of temperatures and gravitational pressure gradients found in some Brazilian reservoirs, i.e., at temperatures of (333.15 and 353.15) K and pressure up to 68.9 MPa
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