Date of Graduation


Document Type


Degree Type



Statler College of Engineering and Mineral Resources


Petroleum and Natural Gas Engineering

Committee Chair

Huseyin I Bilgesu

Committee Co-Chair

Sam Ameri

Committee Member

Kashy Aminian


In order to reduce Green House Gases, Carbon-dioxide (CO2) storage in deep saline aquifers is a viable commercial application for minimizing emissions. It is important to understand surface area needed to predict large scale CO2 storage while fully utilizing injection capacity. This study presents results from varying Injection pressure and well spacing to find minimal-effective well spacing required to store CO2. The study shows pressure management to manipulate hydrodynamic behavior of CO 2 in saline formations system. In conjunction, understanding the interplay of CO2 dissolution, buoyancy flow, and capillary forces in regulating the behavior of the injected CO2 plume are important. Pressure manipulated by changing injection pressure with selected brine co-production, a technique known as CO2 sequestration.;A 3-D reservoir model has been utilized to model CO2 sequestration behavior in a compositional simulator, CMG Builder. Mount Simon Sandstone (Cambrian) was selected as a 'base case model' for its recognition as an important deep saline reservoir with potential to serve as a largescale commercial CO2 storage field in the Midwestern United States.;The study shows the impact of selected injection pressure on the utilization of brine aquifer. It is recommended to store CO2 with 4000 -- 4500 psi injection pressure range for optimum storage and production conditions.