Degree

Master of Science in Engineering (MSE)

Department

Petroleum Engineering

Document Type

Thesis

Abstract

As global initiatives to mitigate greenhouse gas emissions intensify, depleted unconventional shale gas formations have emerged as critical candidates for large-scale geological carbon storage (GCS). This study investigates the feasibility, dynamic trapping mechanisms, and operational optimization of CO₂ sequestration in deep, low-permeability shale reservoirs, using the Upper Jurassic Haynesville Shale in northwest Louisiana as a comprehensive case study. Compositional reservoir simulation (CMG GEM 2021.10) was performed using the SPE Haynesville dataset, with CO₂ injected at a rate of 10,000 ft³/day across single and multiple depth intervals spanning 11,290–11,314 feet. Results demonstrate that multi-depth injection significantly improves residual trapping, reduces buoyancy-driven plume migration, and enhances horizontal CO₂ confinement within the formation. The CO₂ plume expands in a highly symmetrical, radial pattern, migrating upward due to buoyancy and accumulating beneath the Bossier Shale caprock. Rock-fluid characterization reveals extreme capillary entry pressures and ultra-low matrix permeability that govern storage dynamics. Collectively, these results provide critical insights for designing optimal injection strategies to maximize CCUS efficiency while minimizing leakage risk in geopressured shale systems. Keywords: CO₂ sequestration; geological carbon storage; Haynesville Shale; compositional simulation; plume migration; capillary trapping; CCUS; shale reservoirs; rock-fluid properties; caprock integrity.

Date

2-6-2026

DOI

https://proquest.com/docview/3347815157

First Committee Chair

Ning Liu

First Committee Member

Boyun Guo

Second Committee Member

Fathi H Boukadi

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