Chemical mechanisms of dissolution of calcite by HCl in porous media: Simulations and experiment

Gray, F.; Anabaraonye, Benaiah U.; Shah, Saurabh; Boek, Edo S.; Crawshaw, John

doi:10.1016/j.advwatres.2018.09.007

Cited by 45 publications

(31 citation statements)

References 38 publications

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“…It has previously been observed for consolidated sandstone, where Mg-calcite dissolved, that a higher permeability resulted (Gray et al, 2018;Luquot & Gouze, 2009). In order to clarify how the pore morphology in unconsolidated sandstone changes and how precisely the permeability is affected, we investigated how the petrophysical properties of an unconsolidated sandstone are rendered by CO 2 -saturated (live) brine injection via in situ X-ray μCT, simulating true storage conditions.…”

Section: Discussionmentioning

confidence: 87%

CO₂‐Saturated Brine Injection Into Unconsolidated Sandstone: Implications for Carbon Geosequestration

Zhang

et al. 2019

JGR Solid Earth

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Carbon dioxide (CO 2 ) injection into deep depleted hydrocarbon reservoirs or saline aquifers is currently considered the best approach to large-scale CO 2 storage. Importantly, the pore structure and permeability of the storage rock are affected by fines release, migration, and reattachment in the initial stage of CO 2 injection, especially in unconsolidated sandstone reservoirs. It is thus necessary to better understand the pore structure changes and the associated permeability evolution during and after CO 2 injection. We thus imaged an unconsolidated sandstone at reservoir conditions before and after CO 2 -saturated brine ("live brine") injection in situ via X-ray microcomputed tomography to explore the effects of fines migration and mineral dissolution induced by CO 2 injection. We found that in the examined sample, large pores dominated the total porosity, and porosity slightly increased after live-brine flooding. Moreover, and importantly, the pore structure changed significantly: large pores were further enlarged while small pores shrank or even disappeared. These structural changes in the tested sample were caused by mobilized fines due to the high-fluid interstitial velocity, which eventually reattached to the grains further downstream. Furthermore, the impact of the pore structural changes on permeability were analyzed in detail numerically. These permeability results are consistent with a fines migration mechanism where reattached fines block pore throats and thus decrease permeability drastically. We therefore can conclude that live brine injected into the examined unconsolidated sandstone will slightly improve storage space (porosity slightly increased); however, injectivity may be severely impaired by the permeability reduction.

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Section: Discussionmentioning

confidence: 87%

CO₂‐Saturated Brine Injection Into Unconsolidated Sandstone: Implications for Carbon Geosequestration

Zhang

et al. 2019

JGR Solid Earth

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“…Atomic force microscopy (AFM) data and simulations show that the adsorbed ions behave as ordered water layers on the calcite surface rather than directly binding to mineral atoms [92][93][94]. Also, calcite's surface properties depend mainly on the history of its exposure-CO 2 increases the acidity of water droplets, which causes calcite to dissolve, changing the local surface morphology [95].…”

Section: Interfacial Tension and Miscibilitymentioning

confidence: 99%

CO2-Fluid-Rock Interactions and the Coupled Geomechanical Response during CCUS Processes in Unconventional Reservoirs

Cai

et al. 2021

Geofluids

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The difficulty of deploying remaining oil from unconventional reservoirs and the increasing CO2 emissions has prompted researchers to delve into carbon emissions through Carbon Capture, Utilization, and Storage (CCUS) technologies. Under the confinement of nanopore in unconventional formation, CO2 and hydrocarbon molecules show different density distribution from in the bulk phase, which leads to a unique phase state and interface behavior that affects fluid migration. At the same time, mineral reactions, asphaltene deposition, and CO2 pressurization will cause the change of porous media geometry, which will affect the multiphase flow. This review highlights the physical and chemical effects of CO2 injection into unconventional reservoirs containing a large number of micro-nanopores. The interactions between CO2 and in situ fluids and the resulting unique fluid phase behavior, gas-liquid equilibrium calculation, CO2 adsorption/desorption, interfacial tension, and minimum miscible pressure (MMP) are reviewed. The pore structure changes and stress distribution caused by the interactions between CO2, in situ fluids, and rock surface are discussed. The experimental and theoretical approaches of these fluid-fluid and fluid-solid reactions are summarized. Besides, deficiencies in the application and safety assessment of CCUS in unconventional reservoirs are described, which will help improve the design and operation of CCUS.

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“…In order to simulate the effect of fluid inclusions -what Gray et al [21] refer to as detailed structure versus the homogeneous equivalent material -we focused on a sub-sample of 128 3 voxels that is characterized by the presence of a large pore in a crescent shape as illustrated in Figure 6. In this sub-sample we enforced boundary conditions inherited from the superficial velocity of the full sample, and began the simulation at t = 0 with the acid inlet at pH = 2 as for the full sample.…”

Section: Dissolution Of a Non-percolating 3d Carbonate Rockmentioning

confidence: 99%

“…Steefel et al (2005) advocated for the use of reactive transport models in earth sciences, yet stressed that capturing the scale-dependence of reactive transport processes is a challenge yet to be overcome [54]. As a concrete example of this scale-dependence, we can cite the work of Gray et al [21]. Confronting experimental results with simulations of calcite dissolution in HCl showed that small morphological features, such as pore-throat size, micro-porosity and specific reactive area, could have a significant impact on the reaction rates and the dissolution patterns obtained.…”

Section: Introductionmentioning

confidence: 99%

Improvement of remeshed Lagrangian methods for the simulation of dissolution processes at pore-scale

Etancelin

Moonen

Poncet

2020

Advances in Water Resources

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This article shows how to consistently and accurately manage the Lagrangian formulation of chemical reaction equations coupled with the superficial velocity formalism introduced in the late 80s by Quintard and Whitaker. Lagrangian methods prove very helpful in problems in which transport effects are strong or dominant, but they need to be periodically put back in a regular lattice, a process called remeshing. In the context of digital rock physics, we need to ensure positive concentrations and regularity to accurately handle stagnation point neighborhoods. These two conditions lead to the use of kernels resulting in extra-diffusion, which can be prohibitively high when the diffusion coefficient is small. This is the case especially for reactive porous media, and the phenomenon is reinforced in porous rock matrices due to Archie's law. This article shows how to overcome this difficulty in the context of a two-scale porosity model applied in the Darcy-Brinkman-Stokes equations, and how to obtain simultaneous sign preservation, regularity and accurate diffusion, and apply it to dissolution processes at the pore scale of actual rocks.

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Chemical mechanisms of dissolution of calcite by HCl in porous media: Simulations and experiment

Cited by 45 publications

References 38 publications

CO₂‐Saturated Brine Injection Into Unconsolidated Sandstone: Implications for Carbon Geosequestration

CO₂‐Saturated Brine Injection Into Unconsolidated Sandstone: Implications for Carbon Geosequestration

CO2-Fluid-Rock Interactions and the Coupled Geomechanical Response during CCUS Processes in Unconventional Reservoirs

Improvement of remeshed Lagrangian methods for the simulation of dissolution processes at pore-scale

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Chemical mechanisms of dissolution of calcite by HCl in porous media: Simulations and experiment

Cited by 45 publications

References 38 publications

CO2‐Saturated Brine Injection Into Unconsolidated Sandstone: Implications for Carbon Geosequestration

CO2‐Saturated Brine Injection Into Unconsolidated Sandstone: Implications for Carbon Geosequestration

CO2-Fluid-Rock Interactions and the Coupled Geomechanical Response during CCUS Processes in Unconventional Reservoirs

Improvement of remeshed Lagrangian methods for the simulation of dissolution processes at pore-scale

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CO₂‐Saturated Brine Injection Into Unconsolidated Sandstone: Implications for Carbon Geosequestration

CO₂‐Saturated Brine Injection Into Unconsolidated Sandstone: Implications for Carbon Geosequestration