A particulate rock model to simulate thermomechanical cracks induced in the near well by supercritical CO2 injection

Peter-Borie, Mariane; Blaisonneau, Arnold; Gentier, Sylvie; Rachez, Xavier; Shiu, W.Y.; Dedecker, Fabian

doi:10.5242/iamg.2011.0148

Cited by 2 publications

(2 citation statements)

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“…Among these perturbations, the desiccation of the porous medium appears to be a major phenomenon with various positive or negative implications such as salt precipitation (Peysson et al, 2010, Ott et al, 2010a, modifications of the local geomechanical constraints and internal forces (Peter-Borie et al, 2011), and impacts of injected fluids on the interfacial tensions including capillary/osmotic phenomena (Leroy et al, 2010). Desiccation of porous media subjected to gas injection has been investigated at the laboratory scale on cores (Mahadevan, 2005;Mahadevan et al, 2007;Peysson, 2012) and on a chip (Kim et al, 2013).…”

Section: Introductionmentioning

confidence: 99%

Well injectivity during CO2 storage operations in deep saline aquifers – Part 2: Numerical simulations of drying, salt deposit mechanisms and role of capillary forces

André

Peysson

Azaroual

2014

International Journal of Greenhouse Gas Control

102

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The injection of CO 2 into geological reservoirs or deep saline aquifers is being studied to control global warming by limiting greenhouse gas emissions. CO is captured from exhaust gases in power plants or industrial units and stored in underground geological reservoirs. Return on experience withCO 2 injection in the oil industry clearly shows that injectivity problems can be encountered due to several mechanisms including mineral dissolution/ precipitationand physical alteration due to the complete desaturation of the near-wellbore zone. This study describes numerical modelling that is able to reproduce the experimental results of drying of brine-saturated sandstone cores by gas injection in the laboratory. The evolution of water and gas saturation profiles and the precipitation of salt inside the samples are followed with injection time. Numerical results agree well with experimental observations highlighting the key role played by capillary forces during the desiccation process (see the companion paper; Peysson et al., 2013). A tentative extrapolation of experimental results from laboratory scale to the near-well field scale is proposed. This approach is of major importance because it makes it possible to determine the optimal CO 2 injection flow rate according to both the intrinsic petrophysical properties of the porous medium and initial brine salinities.

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Section: Introductionmentioning

confidence: 99%

Well injectivity during CO2 storage operations in deep saline aquifers – Part 2: Numerical simulations of drying, salt deposit mechanisms and role of capillary forces

André

Peysson

Azaroual

2014

International Journal of Greenhouse Gas Control

102

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“…The elaboration of the numerical rock model setup is a preliminary essential task, often difficult due to insufficient data and thus high level of uncertainties. Before any numerical modeling, the real rock (here a dolerite) is conceptualized according to the role of each mineral phases in the behavior of the rock (more details in Peter-Borie et al 2011. The dolerites are typical shallow intrusive bodies; they are micrograined, composed entirely of 1-5-mm-wide crystallized minerals without glassy matter.…”

Section: Numerical Rock Setupmentioning

confidence: 99%

Borehole damaging under thermo-mechanical loading in the RN-15/IDDP-2 deep well: towards validation of numerical modeling using logging images

et al. 2018

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A wider exploitation of deep geothermal reservoir requires the development of Enhanced Geothermal System technology. In this context, drilling and stimulation of high-enthalpy geothermal wells raise technical challenges. Understanding and predicting the rock behavior near a deep geothermal wellbore are decisive to implement stimulation strategies to reach the couple temperature/flowrate target. Numerical modeling can contribute to enhanced stimulation processes thanks to a better understanding of impact of stress release, pressure changes and rock cooling in the near-wellbore area. In this paper, we use Discrete Element Method (code PFC2D, © Itasca Consulting Group), and more specifically bonded-particle model to capture the thermo-mechanical processes at metric scale. The application case corresponds to the beginning of thermal stimulation at Reykjanes in well RN-15/IDDP-2 (Iceland, IDDP-2 project and H2020 project DEEPEGS). A cold fluid is injected at a depth of 4.5 km where the rock temperature is above 430 °C and the well pressure is around 34 MPa. Since we have site-specific data and logging images after drilling, we attempt to link the simulations with the reality. The numerical results are confronted with incipient interpretation of logging images and with analytical solution to go towards validation of the modeling approach. Numerical results show breakouts and thermally and/or mechanically induced fractures consistent with the analytical solutions. Moreover, the sensitivity analysis on uncertain parameters yields important clues regarding some logging features as, for example, asymmetric damaging or caving.

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A particulate rock model to simulate thermomechanical cracks induced in the near well by supercritical CO2 injection

Cited by 2 publications

References 0 publications

Well injectivity during CO2 storage operations in deep saline aquifers – Part 2: Numerical simulations of drying, salt deposit mechanisms and role of capillary forces

Well injectivity during CO2 storage operations in deep saline aquifers – Part 2: Numerical simulations of drying, salt deposit mechanisms and role of capillary forces

Borehole damaging under thermo-mechanical loading in the RN-15/IDDP-2 deep well: towards validation of numerical modeling using logging images

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