Fluid‐Rock Interactions in Clay‐Rich Seals

Skurtveit, Elin; Miri, Rohaldin; Hellevang, Helge

doi:10.1002/9781119118657.ch8

Cited by 4 publications

(3 citation statements)

References 113 publications

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“…Extensive researches have been performed to improve understanding of the impacts of various fluid-rock reactions on the sealing efficiency/integrity of caprock under the context of geological carbon storage (Espinoza and Santamarina 2012;Kampman et al 2014aKampman et al , 2014bSkurtveit et al 2018). Most of such studies have focused on carbonate dissolution/ precipitation reactions and their effects on reactive permeability evolution (Armitage et al 2013;Kampman et al 2014a;Wollenweber et al 2010;Wolterbeek et al 2013).…”

Section: Introductionmentioning

confidence: 99%

“…Most of such studies have focused on carbonate dissolution/ precipitation reactions and their effects on reactive permeability evolution (Armitage et al 2013;Kampman et al 2014a;Wollenweber et al 2010;Wolterbeek et al 2013). It is commonly observed that rock-fluid interactions (e.g., dissolution of formation rock and caprock, precipitation of secondary mineral phases) occurring in CO 2 storage system can lead to changes in pore structure and alternation of flow pathway, which in turn affects the transport properties of the reservoir and caprock (Rochelle et al 2004;Skurtveit et al 2018). However, possible alternation in transport properties within smectite-bearing clay-rich caprocks and fault gouges, induced by the experimentally confirmed swelling and shrinking of smectites due to CO 2 sorption, is poorly addressed in the literature (Skurtveit et al 2018) except for a couple of modeling studies (Akono et al 2019;Wentinck and Busch 2017).…”

Section: Introductionmentioning

confidence: 99%

“…It is commonly observed that rock-fluid interactions (e.g., dissolution of formation rock and caprock, precipitation of secondary mineral phases) occurring in CO 2 storage system can lead to changes in pore structure and alternation of flow pathway, which in turn affects the transport properties of the reservoir and caprock (Rochelle et al 2004;Skurtveit et al 2018). However, possible alternation in transport properties within smectite-bearing clay-rich caprocks and fault gouges, induced by the experimentally confirmed swelling and shrinking of smectites due to CO 2 sorption, is poorly addressed in the literature (Skurtveit et al 2018) except for a couple of modeling studies (Akono et al 2019;Wentinck and Busch 2017). Moreover, most flow through experiments were conducted under controlled (effective) confining stress conditions (e.g., Gaus et al 2005;Wollenweber et al 2010), which are poorly representative for the near-zero lateral strain conditions encountered in the subsurface.…”

Section: Introductionmentioning

confidence: 99%

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Effect of CO2-H2O-Smectite Interactions on Permeability of Clay-Rich Rocks Under CO2 Storage Conditions

2023

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CO 2 uptake by smectites can cause swelling and self-stressing in shallow clay-rich caprocks under CO 2 storage P-T and constrained conditions. However, little data exist to constrain the magnitude of the effects of CO 2 -H 2 O-smectite interactions on the sealing properties of clay-rich caprocks and faults. We performed permeability experiments on intact and fractured Opalinus Claystone (OPA) cores (~ 5% smectite), as well as on a simulated gouge-filled faults consisting of Na-SWy-1 montmorillonite, under radially constrained conditions simulating "open" transport pathways (dry and variably wet He or CO 2 ; 10 MPa fluid pressure; 40 °C). Overall, the flow of dry CO 2 through intact OPA samples and simulated smectite fault gouge caused a decrease in permeability by a factor of 4-9 or even by > 1 order, compared to dry He permeability. Subsequent to flow of dry and partially wet fluid, both fractured OPA and simulated gouge showed a permeability reduction of up to 3 orders of magnitude once flow-through with wet CO 2 was performed. This permeability change appeared reversible upon re-establishing dry CO 2 flow, suggesting fracture permeability was dominated by water uptake or loss from the smectite clay, with CO 2 -water-smectite interactions play a minor effect. Our results show that whether an increases or decreases in permeability of clayey caprock is expected with continuous flow of CO 2 -rich fluid depends on the initial water activity in the clay material versus the water activity in the CO 2 bearing fluid. This has important implications for assessing the self-sealing potential of fractured and faulted clay-rich caprocks. Highlights• Permeability of potential clay-rich caprock (Opalinus Claystone) was systematically measured using variably wet CO 2 versus He. • Through-flow of dry CO 2 caused a decrease in permeability of intact Opalinus Claystone and simulated smectite fault gouge by up to > 1 order, as composed to dry He. • Fractured Opalinus Claystone and simulated gouge showed a permeability reduction of up to 3 orders of magnitude with through-flow of wet CO 2 . • Permeability decrease by through-flow of variably wet CO 2 appeared reversible upon re-establishing dry CO 2 flow. • The initial water activity in the clay material versus the water activity in the CO 2 bearing fluid determines change in permeability upon CO 2 flushing. Keywords Shale permeability • CO 2 storage • Clay swelling • CO 2 -H 2 O-smectite interactions * M. Zhang

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Effect of CO2-H2O-Smectite Interactions on Permeability of Clay-Rich Rocks Under CO2 Storage Conditions

2023

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Long-term integrity of shaly seals in CO2 geo-sequestration sites: An experimental study

Gholami

Raza

Andersen

et al. 2021

International Journal of Greenhouse Gas Control

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Evaluation of Caprock Sealing Performance for CO2 Saline Aquifer Storage: A Numerical Study

Shu,

Zhang,

Zhang

et al. 2024

Processes

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The integrity of caprock sealing is a crucial factor in guaranteeing the safety and long-term feasibility of CO2 saline aquifer storage. In this study, we identified three principal mechanisms that give rise to topseal failure: (1) gradual CO2 seepage through the upper cap, (2) capillary seal failure resulting from the pressure increment due to CO2 injection, and (3) localized overpressure causing cap rupture. Through the integration of numerical simulation and geomechanics, this study offers a sealing assessment for the caprock. The thorough analysis of the sealing performance of the Guantao formation reveals that after 2000 years of CO2 injection, the caprock would undergo intrusion by 35 m without any leakage risk. Moreover, investigations into CO2-water–rock interactions suggest that precipitation reactions outweigh dissolution reactions, leading to a decreased permeability and an enhanced sealing performance. The most likely fracture mode identified is shear fracture with a critical caprock fracture pressure of 36.48 MPa. In addition to these discoveries, it is significant to consider ongoing research aimed at enhancing our ability to predict and manage potential risks associated with carbon capture and storage technologies.

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Fluid‐Rock Interactions in Clay‐Rich Seals

Cited by 4 publications

References 113 publications

Effect of CO2-H2O-Smectite Interactions on Permeability of Clay-Rich Rocks Under CO2 Storage Conditions

Effect of CO2-H2O-Smectite Interactions on Permeability of Clay-Rich Rocks Under CO2 Storage Conditions

Long-term integrity of shaly seals in CO2 geo-sequestration sites: An experimental study

Evaluation of Caprock Sealing Performance for CO2 Saline Aquifer Storage: A Numerical Study

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