Understanding Confined Fluids in Shale Gas Systems

Edward Alan Thomas, University of Rhode Island


Given the complexity of shale gas at high pressures, researchers aim to characterize the thermodynamic properties of confined fluids using a mixture of experimental, modeling, and simulation techniques. In this work we frequently use the predictive capabilities of simulation to couple the property results to models. The overall results are then compared to experimental data for verification purposes. ^ We employ a Monte Carlo simulation technique to ensure that a simple linear mixing rule for internal energies of departure holds thereby allowing pure component data to extend to mixtures. The results are coupled to the GHC EOS allowing for bulk-scale bubble point reduction predictions. In addition, the sensitivity of the results is determined. ^ Adsorption of high pressure fluids is studied as a function of carbon chain length, temperature, and pore throat size to give an overall picture of shale gas behavior at reservoir conditions. A simple model is shown to provide a reasonable estimate of the isotherms at high pressures. Under the assumption of ideal site-site interactions, mixtures are predicted and compared to work in the literature. ^ An important aspect of this work is the verification to experimental data, we expand on recent work by characterizing the experimental to simulation data in a robust manner. Quantitative agreement is achieved when considering the surface area and void volume of the porous material.^

Subject Area

Fluid mechanics|Chemical engineering|Petroleum engineering

Recommended Citation

Edward Alan Thomas, "Understanding Confined Fluids in Shale Gas Systems" (2018). Dissertations and Master's Theses (Campus Access). Paper AAI10690064.