Spatial Distribution of Pressure Build-up from CO2 Injection in Saline Aquifers
Abstract
Injectivity is one of several key parameters that determine the effective CO2 geologic storage. In general, the injectivity depends on various factors including the product of formation permeability and formation thickness, relative permeability, salt precipitation in the dry-out zone and porosity reduction due to mineral precipitation. In this study we focused on investigating the pressure build-up near the injection well and CO2 plume behavior throughout the formation by varying the perforated zone, borehole skin, and injection period. For this purpose, a two-dimensional radial model was designed to assess the spatial distribution of pressure build-up and CO2 plume over time. We performed three cases of simulations to examine the effect of injection perforation on the pressure distribution by injecting CO2 at the lower, middle, and upper part of the target formation. In addition, the borehole skin effect was examined by setting a high permeable zone immediately adjacent to the injection well and the effect of injection period was also examined by setting up scenarios for injection shutdowns which caused change of pressure and gas saturation distribution in the model domain. Through these series of simulations, we investigated the spatial range of the dry-out zone, the timing for a complete dry-out process, amount of salt precipitation and corresponding porosity-permeability reduction.
- Publication:
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AGU Fall Meeting Abstracts
- Pub Date:
- December 2009
- Bibcode:
- 2009AGUFM.H13E1029K
- Keywords:
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- 1847 HYDROLOGY / Modeling;
- 1857 HYDROLOGY / Reservoirs