Joule-Thomson cooling due to CO2 injection into natural gas reservoirs

Oldenburg, Curtis M.

doi:10.1016/j.enconman.2007.01.010

Cited by 199 publications

(85 citation statements)

References 10 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…In addition, studies of thermal effects of injecting high-pressure CO 2 into low-pressure depleted reservoirs have been made (Oldenburg 2007;Maloney and Briceno 2009;Mathias et al 2010). The drastic changes in CO 2 properties arising from mixing with CH 4 are well known (e.g., Oldenburg et al 2004a,b) and the associated potential beneficial uses have been noted (Oldenburg 2007). None of these prior studies has investigated the effects of residual gas saturation in general, or the compositional effects associated with mixing supercritical CO 2 and residual CH 4 gas in particular.…”

Section: Prior Workmentioning

confidence: 99%

Injection, Flow, and Mixing of CO2 in Porous Media with Residual Gas

Oldenburg

Doughty

2010

Transp Porous Med

View full text Add to dashboard Cite

Geologic structures associated with depleted natural gas reservoirs are desirable targets for geologic carbon sequestration (GCS) as evidenced by numerous pilot and industrial-scale GCS projects in these environments world-wide. One feature of these GCS targets that may affect injection is the presence of residual CH 4 . It is well known that CH 4 drastically alters supercritical CO 2 density and viscosity. Furthermore, residual gas of any kind affects the relative permeability of the liquid and gas phases, with relative permeability of the gas phase strongly dependent on the time-history of imbibition or drainage, i.e., dependent on hysteretic relative permeability. In this study, the effects of residual CH 4 on supercritical CO 2 injection were investigated by numerical simulation in an idealized one-dimensional system under three scenarios: (1) with no residual gas; (2) with residual supercritical CO 2 ; and (3) with residual CH 4 . We further compare results of simulations that use non-hysteretic and hysteretic relative permeability functions. The primary effect of residual gas is to decrease injectivity by decreasing liquid-phase relative permeability. Secondary effects arise from injected gas effectively incorporating residual gas and thereby extending the mobilegas plume relative to cases with no residual gas. Third-order effects arise from gas mixing and associated compositional effects on density that effectively create a larger plume per unit mass. Non-hysteretic models of relative permeability can be used to approximate some parts of the behavior of the system, but fully hysteretic formulations are needed to accurately model the entire system.

show abstract

Section: Prior Workmentioning

confidence: 99%

Injection, Flow, and Mixing of CO2 in Porous Media with Residual Gas

Oldenburg

Doughty

2010

Transp Porous Med

View full text Add to dashboard Cite

show abstract

“…Profiles of pressure difference, P − Pw, temperature, T, and CO2 mass fraction in the gas phase, X CO 2 g , at six different times. The dashed lines are from the TOUGH2 simulation previously presented by Oldenburg (2007a). The solid lines are from the analytical solution with pressure, temperature and X CO 2 g calculated from Eqs.…”

Section: The Mathematical Modelmentioning

confidence: 99%

“…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;André et al, 2010). For wider accessibility and application, analytical solutions are preferable, especially those that can be implemented in simple spreadsheet software (e.g.…”

Section: Introductionmentioning

confidence: 99%

Analytical solution for Joule–Thomson cooling during CO2 geo-sequestration in depleted oil and gas reservoirs

Mathias

Gluyas

Oldenburg

et al. 2010

International Journal of Greenhouse Gas Control

Self Cite

View full text Add to dashboard Cite

Mathematical tools are needed to screen out sites where Joule Thomson cooling is a prohibitive factor for CO 2 geosequestration 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).

show abstract

“…These include cooling due to expansion, heating due to compression, heating and cooling due to dissolution and vaporization, respectively, differences in temperature associated with injection and reservoir fluids, and heating due to viscous heat dissipation (Oldenberg 2007;Andre, Azaroual & Menjoz 2010;Han et al 2010). Owing to the Joule-Thomson coefficient of CO 2 being larger at lower pressures, such processes are likely to be of greater significance in low-pressure depleted gas reservoirs as opposed to hydrostatic or overpressured saline aquifers .…”

Section: Introductionmentioning

confidence: 99%

Heat transport and pressure buildup during carbon dioxide injection into depleted gas reservoirs

2014

View full text Add to dashboard Cite

In this article, a two-layer vertical equilibrium model for the injection of carbon dioxide into a low-pressure porous reservoir containing methane and water is developed. The dependent variables solved for include pressure, temperature and CO 2 -CH 4 interface height. In contrast to previous two-layer vertical equilibrium models in this context, the compressibility of all material components is fully accounted for. Non-Darcy effects are also considered using the Forchheimer equation. The results show that, for a given injection scenario, as the initial pressure in the reservoir decreases, both the pressure buildup and temperature change increase. A comparison was conducted between a fully coupled non-isothermal numerical model and a simplified model where fluid properties are held constant with temperature. This simplified model was found to provide an excellent approximation when using the injection fluid temperature for calculating fluid properties, even when the injection fluid was as much as ±15 • C of the initial reservoir temperature. The implications are that isothermal models can be expected to provide useful estimates of pressure buildup in this context. Despite the low viscosity of CO 2 at the low pressures studied, non-Darcy effects were found to be of negligible concern throughout the sensitivity analysis undertaken. This is because the CO 2 density is also low in this context. Based on these findings, simplified analytic solutions are derived, which accurately calculate both the pressure buildup and temperature decline during the injection period.

show abstract

Joule-Thomson cooling due to CO2 injection into natural gas reservoirs

Cited by 199 publications

References 10 publications

Injection, Flow, and Mixing of CO2 in Porous Media with Residual Gas

Injection, Flow, and Mixing of CO2 in Porous Media with Residual Gas

Analytical solution for Joule–Thomson cooling during CO2 geo-sequestration in depleted oil and gas reservoirs

Heat transport and pressure buildup during carbon dioxide injection into depleted gas reservoirs

Contact Info

Product

Resources

About