Impacts of SO2 gas impurity within a CO2 stream on reservoir rock of a CCS pilot site: Experimental and modelling approach

Published on Mar 1, 2018in International Journal of Greenhouse Gas Control3.639
· DOI :10.1016/J.IJGGC.2018.01.003
Maryeh Hedayati3
Estimated H-index: 3
(Uppsala University),
Andrew Wigston5
Estimated H-index: 5
(NRCan: Natural Resources Canada)
+ 2 AuthorsAuli Niemi19
Estimated H-index: 19
(Uppsala University)
Sources
Abstract
Abstract In order to evaluate chemical impacts of SO 2 impurity on reservoir rock during CO 2 capture and storage in deep saline aquifers, several batch reactor experiments were performed on laboratory scale using core rock samples from the pilot CO 2 injection site in Heletz. In this experiment, the samples were exposed to pure N 2 (g), pure CO 2 (g), and CO 2 (g) with an impurity of 1.5% SO 2 (g) under reservoir conditions for pressure and temperature (14.5 MPa, 60 °C). Based on the set-up and the obtained experimental results, a batch chemical model was established using the numerical simulation program TOUGHREACT V3.0-OMP. Comparing laboratory and simulation data provides a better understanding of the rock-brine-gas interactions. In addition, it offers an evaluation of the capability of the model to predict chemical interactions in the target injection reservoir during exposure to pure and impure CO 2 . The best match between the geochemical model and experimental data was achieved when the reactive surface area of minerals in the model was adjusted in order to calibrate the kinetic rates of minerals. The simulations indicated that SO 2 (g) tends to dissolve rather quickly and oxidizes under a kinetic control. Hence, it has a stronger effect on the acidity of the brine than pure CO 2 (g) and as a result, increased mineral dissolution and caused the precipitation of sulfate and sulfide minerals. Ankerite, dolomite, and siderite, the most abundant carbonates in the sandstone rock sample, are subject to stronger dissolution in the presence of SO 2 gas. The performed simulations confirmed a slower dissolution rate for ankerite and siderite than for dolomite. The model reproduced the precipitation of pyrite and anhydrite as observed in the laboratory. The dissolution of dolomite observed in the batch reaction test with pure N 2 is assumed to be due to slight contamination with oxygen and modelling supported this. The inclusion of SO 2 increased the porosity over that of the pure CO 2 case, and is thus considered to increase the permeability and injectivity of the reservoir as well. Exposure to SO 2 also increased the concentration of trace elements. The calibrated kinetic parameters determined in this study will be used to model the injection and long-term behavior of CO 2 at the Heletz field site, and may be used for similar geologic reservoirs.
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