Scientific Investigations Report 2011–5083
AbstractAt present, the literature lacks a geologic-based assessment methodology for numerically estimating injectivity, lateral migration, and subsequent long-term containment of supercritical carbon dioxide that has undergone geologic sequestration into subsurface formations. This study provides a method for and quantification of first-order approximations for the time scale of supercritical carbon dioxide lateral migration over a one-kilometer distance through a representative volume of rock. These calculations provide a quantified foundation for estimating injectivity and geologic storage of carbon dioxide. A geologic-based approach was developed in which subsurface pressure and temperature conditions were held constant while the petrophysical properties of fractional porosity and matrix permeability were varied simultaneously. The Span and Wagner equations of state were used to determine thermophysical properties of carbon dioxide at appropriate reservoir conditions. The fluid-flow calculations assume mass transport through a laterally continuous, homogeneous isotropic formation and were based on two constitutive equations from fluid dynamics: hydraulic diffusivity for near-surface applications, and a modified version of Darcy’s Law for deeper formations exhibiting higher pressure gradients. The first-order approximations of the lateral migration time scales, for both hydraulic diffusivity and Darcy flow, can be expressed as a quasi-linear function over a range of porosity and permeability values. This method is applicable to a substantial range of sedimentary formations exhibiting porosities up to 95 percent and permeabilities from 10.0 darcy to 1.0 picodarcy. These results were used to classify subsurface formations into three permeability classifications for the probabilistic calculations of storage efficiency and containment risk of the U.S. Geological Survey geologic carbon sequestration assessment methodology. This methodology is currently in use to determine the total carbon dioxide containment capacity of the onshore and State waters areas of the United States. |
First posted July 26, 2011 For additional information contact: Part or all of this report is presented in Portable Document Format (PDF); the latest version of Adobe Reader or similar software is required to view it. Download the latest version of Adobe Reader, free of charge. |
Burke, Lauri, 2011, Carbon dioxide fluid-flow modeling and injectivity calculations: U.S. Geological Survey Scientific Investigations Report 2011–5083, 16 p.
Abstract
Introduction
Methodology
Fluid-Flow Modeling
Hydraulic Diffusivity
Sensitivity Analysis for Hydraulic Diffusivity Flow Modeling
Darcy’s Law of Fluid Flow
Injectivity
The Maximum Pressure Differential for Injectivity
Results from Darcy’s Law of Fluid Flow
Darcy Sensitivity Analysis
Permeability Classifications
Discussion and Conclusions
Acknowledgments