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• W2093547237 abstract "Analytical solution for Joule–Thomson cooling during CO 2 geo-sequestration in depleted oil and gas reservoirs Simon A. Mathias a *, Jon G. Gluyas a , Curtis M. Oldenburg b , Chin-Fu Tsang b b Department of Earth Sciences, Durham University, Durham, UK Earth Sciences Division, Lawrence Berkeley National Laboratory, Berkeley, CA, USA a ABSTRACT Mathematical tools are needed to screen out sites where Joule Thomson cooling is a prohibitive factor for CO 2 geo- sequestration and to design approaches to mitigate the effect. In this paper, a simple analytical solution is developed by invoking steady-state flow and constant thermophysical properties. The analytical solution allows fast evaluation of spatiotemporal temperature fields, resulting from constant-rate CO 2 injection. The applicability of the analytical solution is demonstrated by comparison with non-isothermal simulation results from the reservoir simulator TOUGH2. Analysis confirms that for an injection rate of 3 kgs−1 (0.1MTyr−1) into moderately warm(>40°C) and permeable formations(>10 −14 m 2 (10 mD)), JTC is unlikely to be a problem for initial reservoir pressures as low as2 MPa (290 psi). Keywords: Joule–Thomson cooling Geologic carbon sequestration Depleted gas reservoirs 1. Introduction Depleted oil and gas reservoirs (DOGRs) represent a significant portion of the global portfolio of target formations currently under consideration for CO 2 geo-sequestration (Benson and Cook, 2005). There are two major advantages associated with DOGRs:(1) they have been extensively characterized during exploration, appraisal and production; (2) they are already proven as potentially long- term traps for buoyant fluids owing to their ability to store oil and gas over tens to hundreds of millions of years(Maloney and Briceno, 2009). However, low pore-pressures, characteristic of depletion- drive reservoirs at cessation of production, will lead to significant Joule–Thomson cooling (JTC) when large pressure gradients are developed due to CO 2 injection. JTC is the name given to the drop in temperature that occurs when a real gas such as CO 2 expands from high pressure to low pressure at constant enthalpy (i.e., adiabatic expansion) (see Oldenburg, 2007b, for further detail). Of particular concern is the severe loss of injectivity that may develop due to freezing of pore fluids (e.g., native brine)and/or the generation of CO 2 or CH 4 hydrates, effectively rendering the injection well dysfunctional (Oldenburg, 2007b). Mathematical tools are needed to identify and evaluate sites where JTC is a prohibitive factor for CO 2 geo-sequestration and to aid in the design of approaches to mitigate the effect. Previously JTC during CO 2 geo-sequestration has been explored using laboratory experiments (Maloney and Briceno, 2009) and numerical simulation (Oldenburg, 2007a; Bielinski et al., 2008; Andre et al., 2010). For wider accessibility and application, analytical solutions are preferable, especially those that can be implemented in simple spreadsheet software (e.g. Oldenburg, 2007b; Mathias et al., 2009a,b). Unfortunately, analytical solution of the full JTC problem is not possible due to the non-linear coupling between the associated fluid flow and thermal transport equations. However, for the low pressures of interest, the Joule–Thomson coefficient for CO 2 remains relatively constant (see Andre et al., 2010, Fig. 1). It is therefore hypothesized that meaningful results can be obtained when thermophysical properties are assumed constant and uniform. In this paper, a simple analytical solution is developed by invoking steady-state flow and constant thermophysical properties. The analytical solution allows fast evaluation of spatiotemporal temperature fields resulting from constant-rate CO 2 injection. The applicability of the analytical solution is demonstrated by comparison with fully coupled and transient non-isothermal simulation results from the reservoir simulator TOUGH2/EOS7C (Oldenburg et al., 2004a). Sensitivity analysis of the analytical solution is explored to provide insight into the importance of JTC for DOGRs. 2. The mathematical model Consider the constant-rate injection of fluid from a fully penetrating injection well into an infinite, homogenous and isotropic, insulated and confined formation. As mentioned previously, for the low pressures of interest, the Joule–Thomson coefficient for CO 2 remains relatively constant. It is therefore hypothesized that meaningful results can be obtained when thermophysical properties are" @default.
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• W2093547237 date "2010-09-01" @default.
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• W2093547237 title "Analytical solution for Joule–Thomson cooling during CO2 geo-sequestration in depleted oil and gas reservoirs" @default.
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• W2093547237 doi "https://doi.org/10.1016/j.ijggc.2010.05.008" @default.
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