Advances in Numerical Reservoir Simulation for In Situ Upgrading of Heavy Oil via Steam-Based Technologies

Michael Kwofie, Guillermo Félix, Alexis Tirado, Mikhail A. Varfolomeev and Jorge Ancheyta ()
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Michael Kwofie: Department of Petroleum Engineering, Kazan Federal University, Kazan 420008, Russia
Guillermo Félix: Department of Petroleum Engineering, Kazan Federal University, Kazan 420008, Russia
Alexis Tirado: Department of Petroleum Engineering, Kazan Federal University, Kazan 420008, Russia
Mikhail A. Varfolomeev: Department of Petroleum Engineering, Kazan Federal University, Kazan 420008, Russia
Jorge Ancheyta: Department of Petroleum Engineering, Kazan Federal University, Kazan 420008, Russia

Energies, 2025, vol. 18, issue 21, 1-29

Abstract: The numerical reservoir simulation is a valuable tool to enhance heavy oil recovery by assessing different production strategies (like SAGD and CSS) and operational scenarios. While numerous studies have developed complex models, a systematic review identifying the most critical parameters for achieving accurate production forecasts is lacking. In this work, diverse studies have been reviewed regarding the numerical models of steam injection technologies by examining various parameters (reservoir properties and operating conditions) employed and their impact on the results obtained. Additionally, the effect of using kinetic models in simulations, as well as the modeling of solvent and catalyst injection, is discussed. The outcomes highlight that oil recovery for steam injection methods requires effective steam chamber management and an understanding of geomechanical changes due to the significant role of thermal convection on energy transfer and oil displacement. Increasing steam injection pressures can enhance energy efficiency and reduce emissions, but controlling the gases generated during the reaction poses difficulties. The gas formation within the reservoir in simulations is crucial to prevent overestimating oil production and improving precision. This can be achieved using simple kinetic models, but it is essential to incorporate gas–water solubilities to mimic actual gas emissions and avoid gas buildup. Crucially, our synthesis of the literature demonstrates that incorporating gas–water solubilities and kinetic models for H 2 S production can improve the prediction accuracy of gas trends by up to 20% compared to oversimplified models. Enhanced recovery methods (adding solvent and catalyst injection) provide advantages compared with conventional steam injection methods. However, suitable interaction models between oil components and solid particles are needed to improve steam displacement, decrease water production, and enhance recovery in certain circumstances. The use of complex reaction schemes in numerical modeling remarkably enhances the prediction of experimental reservoir data.

Keywords: numerical reservoir simulation; in situ upgrading; heavy crude oil recovery; steam injection technologies (search for similar items in EconPapers)
JEL-codes: Q Q0 Q4 Q40 Q41 Q42 Q43 Q47 Q48 Q49 (search for similar items in EconPapers)
Date: 2025
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