As for conventional cubic equations of state (CEOSs), they find their limits in precisely predicting phase behaviour in systems featuring a broad spectrum of molecular sizes, especially liquid densities. Based on the perturbation theory, the statistical associating fluid theory (SAFT) has been used as a standard approach to describe how complex fluids and fluid mixtures with a substantial disparity in molecular sizes behave; however, its application is still limited in heavy oil-associated mixtures due to fundamental and technical challenges. In this work, a perturbed-chain (PC) SAFT equation of state (EOS) has been developed to characterize heavy oil-associated systems containing polar components (e.g., dimethyl ether (DME) and water) and non-polar components (e.g., CO2 and N2) with respect to their phase behaviour and physical properties. Experimentally, constant composition expansion (CCE) tests were meticulously conducted to measure saturation pressure (Psat), phase volume, and phase compositions for CO2/heavy oil, N2/heavy oil, and DME/heavy oil systems in the absence and presence of water, spanning a range of pressure up to 20 MPa and temperature up to 433.2 K. Theoretically, a PC-SAFT EOS model together with temperature-independent binary interaction parameters (BIPs) is integrated to reproduce the measured Psat and other physical properties of the aforementioned systems. It is experimentally found that addition of water into each of the aforementioned systems will increase its Psat compared to that without water. By characterizing heavy oils as four pseudocomponents (PCs), the density (ρ) of the aforementioned systems can be accurately predicted with the root-mean-squared relative error (RMSRE) of 1.84%. Then, the BIPs for each binary pair of the aforementioned systems are obtained by minimizing the discrepancy between the measured Psat and the calculated ones. The proposed model shows its superior performance over the widely used CEOS (i.e., Peng-Robinson EOS) with an RMSRE of 2.93% for the predicted Psat of the aforementioned systems. The theoretical model proposed in this study excels to reproduce the experimentally measured phase behaviour and physical properties under reservoir conditions, allowing us to accurately evaluate and optimize the hybrid steam-solvent processes in a heavy oil reservoir.
