Reservoir Simulation of CO<sub>2</sub> Flooding vs. CO<sub>2</sub> Huff-and-Puff in Shale Formations: Comparative Analysis of Storage and Recovery Mechanisms

Reservoir Simulation of CO<sub>2</sub> Flooding vs. CO<sub>2</sub> Huff-and-Puff in Shale Formations: Comparative Analysis of Storage and Recovery Mechanisms

Anthropogenic CO<sub>2</sub> emissions are a major driver of climate change, highlighting the urgent need for effective mitigation strategies. Carbon Capture, Utilization, and Storage (CCUS) offers a promising approach, particularly through CO<sub>2</sub>-enhanced gas recover...

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Bibliographic Details
Main Authors: Nazerke Zhumakhanova, Kamy Sepehrnoori, Dinara Delikesheva, Jamilyam Ismailova, Fadi Khagag
Format: Article
Language:English
Published: MDPI AG 2025-06-01
Series:Energies
Subjects:
CO<sub>2</sub> sequestration
CO<sub>2</sub> injection
shale gas
reservoir simulation
enhanced gas recovery
Online Access:https://www.mdpi.com/1996-1073/18/13/3337
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Summary:Anthropogenic CO<sub>2</sub> emissions are a major driver of climate change, highlighting the urgent need for effective mitigation strategies. Carbon Capture, Utilization, and Storage (CCUS) offers a promising approach, particularly through CO<sub>2</sub>-enhanced gas recovery (EGR) in shale reservoirs, which enables simultaneous hydrocarbon production and CO<sub>2</sub> sequestration. This study employs a numerical simulation model to compare two injection strategies: CO<sub>2</sub> flooding and huff-and-puff (H&P). The results indicate that, without accounting for key mechanisms such as adsorption and molecular diffusion, CO<sub>2</sub> H&P provides minimal improvement in methane recovery. When adsorption is included, methane recovery increases by 9%, with 14% of the injected CO<sub>2</sub> stored over 40 years. Incorporating diffusion enhances recovery by 19%, although with limited storage potential. In contrast, CO<sub>2</sub> flooding improves methane production by 26% and retains up to 94% of the injected CO<sub>2</sub>. Higher storage efficiency is observed in reservoirs with high porosity and low permeability, particularly in nano-scale pore systems. Overall, CO<sub>2</sub> H&P may be a viable EGR option when adsorption and diffusion are considered, while CO<sub>2</sub> flooding demonstrates greater effectiveness for both enhanced gas recovery and long-term CO<sub>2</sub> storage in shale formations.
ISSN:1996-1073

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