A Theoretical and Experimental Approach to the Analysis of Hydrogen Generation and Thermodynamic Behavior in an In Situ Heavy Oil Upgrading Process Using Oil-Based Nanofluids

• Published in: Catalysts 2022-11, Vol.12 (11), p.1349
• Main Authors: Medina, Oscar E., Céspedes, Santiago, Zabala, Richard D., Franco, Carlos A., Pérez-Cadenas, Agustín F., Carrasco-Marín, Francisco, Lopera, Sergio H., Cortés, Farid B., Franco, Camilo A.
• Format: Article
• Language: English
• Subjects: Adsorption; Alternative energy sources; Analysis; Asphaltenes; Carbon footprint; Catalysts; Catalytic cracking; Cerium oxides; Chemical potential; Chemical reactions; Crude oil; crude oil upgrading; Decomposition; Emissions; Energy resources; Equations of state; Fluids; Fossil fuels; Fugacity; Heavy petroleum; Hydrocarbons; Hydrogen; Hydrogen production; Mixing rules; Molecular weight; Nanofluids; Nanoparticles; Nanotechnology; Oil recovery; Reservoirs; Resins; steam injection; Thermodynamic properties; Thermodynamics; Thermogravimetric analysis; Viscosity
• ISSN: 2073-4344; 2073-4344
• DOI: 10.3390/catal12111349

This study aims to show a theoretical and experimental approach to the analysis of hydrogen generation and its thermodynamic behavior in an in situ upgrading process of heavy crude oil using nanotechnology. Two nanoparticles of different chemical natures (ceria and alumina) were evaluated in asphaltene adsorption/decomposition under a steam atmosphere. Then, a nanofluid containing 500 mg·L−1 of the best-performing nanoparticles on a light hydrocarbon was formulated and injected in a dispersed form in the steam stream during steam injection recovery tests of two Colombian heavy crude oils (HO1 and HO2). The nanoparticles increased the oil recovery by 27% and 39% for HO1 and HO2 regarding the steam injection. The oil recovery at the end of the displacement test was 85% and 91% for HO1 and HO2, respectively. The recovered crude oil showed an increment in API° gravity from 12.4° and 12.1° to 18.5° and 29.2° for HO1 and HO2, respectively. Other properties, such as viscosity and content of asphaltenes and resins with high molecular weight, were positively modified in both crude oils. The fugacity of H2 was determined between the reservoir and overburden pressure and different temperatures, which were determined by the thermal profiles in the displacement test. The fugacity was calculated using the application of virial equations of state with mixing rules based on the possible intermolecular interactions between the components. Hydrogen acquired a higher chemical potential via nanoparticle presence. However, the difference in H2 fugacity between both points is much higher with nanoparticles, which means that hydrogen presents a lower tendency to migrate by diffusion to the high-pressure point. The difference between HO1 and HO2 lies mainly in the fact that the pressure difference between the reservoir and the overburden pressure is greater in HO2; therefore, the difference in fugacity is greater when the pressure differential is greater.