Fractional Flow Analysis of Foam Displacement in Tight Porous Media with Quasi-Static Pore Network Modeling and Core-Flooding Experiments

Jun Yang, Iftekhar Ahmed Shakib, Zeyu Lin, Yunan Song, Yanfeng He, Bo Zhang () and Jing Zhao ()
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Jun Yang: School of Petroleum and Natural Gas Engineering, Changzhou University, Changzhou 213164, China
Iftekhar Ahmed Shakib: School of Petroleum and Natural Gas Engineering, Changzhou University, Changzhou 213164, China
Zeyu Lin: Research Institute of Petroleum Exploration and Development, PetroChina, Beijing 100083, China
Yunan Song: School of Petroleum and Natural Gas Engineering, Changzhou University, Changzhou 213164, China
Yanfeng He: School of Petroleum and Natural Gas Engineering, Changzhou University, Changzhou 213164, China
Bo Zhang: School of Mechanical and Electrical Engineering, Beijing University of Chemical Technology, Beijing 100029, China
Jing Zhao: School of Petroleum and Natural Gas Engineering, Changzhou University, Changzhou 213164, China

Sustainability, 2024, vol. 16, issue 21, 1-21

Abstract: Fractional flow analysis is an efficient tool to evaluate the gas-trapping performance of foam in porous media. The pore-scale simulation study and the core-scale experimental work have been bridged via the fractional flow analysis to distinguish the characteristics of foam displacement inside the tight porous media with varying absolute permeability, injection rate, and foam quality. In this work, the combined investigation suggests that conventional foam-enhancing strategies, pursuing higher foam quality and stronger foam regime, are inefficient and restricted in tight reservoirs that the critical S w corresponding to the limiting capillary pressure has increased around 37~43%, which indicates severely weakened gas-trapping capacity as permeability reduces one order of magnitude. The moderate mobility adjustment and corresponding optimized fluid injectivity exerting from the “weak foam” flow presents a staged decline feature of decreasing water fractional flow, which implies the existence of the delayed gas-trapping phenomenon when water saturation reduces to 0.5~0.6. The finding has supported the engineering ideal of promoting low-tension gas (LTG) drive processes as a potential solution to assist field gas injection applications suffering from gas channeling. Also, the validation with core-flooding experimental results has revealed several defects of the current pore network model of foam displacement in tight porous media, including exaggerated gas trapping and overestimated confining water saturation. This study has innovatively demonstrated the feasibility and potential of optimizing the foam performance of gas trapping and mobility control in tight reservoirs, which provides a clue that may eventually boost the efficiency of the gas injection process in enhanced oil recovery or CO 2 sequestration projects.

Keywords: foam; gas injection; enhanced oil recovery; CO 2 sequestration; pore network model (search for similar items in EconPapers)
JEL-codes: O13 Q Q0 Q2 Q3 Q5 Q56 (search for similar items in EconPapers)
Date: 2024
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