Evaluation of CO2 injection in shale gas reservoirs with multi-component transport and geomechanical effects

Kim, Tae Hong; Cho, Jinhyung; Lee, Kun Sang

doi:10.1016/j.apenergy.2017.01.047

Cited by 183 publications

(75 citation statements)

References 32 publications

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“…However, if TOC is above 1.1 wt %, the shale is CO 2 -wet. Although such shale may not be suitable as caprock, it may provide a large CO 2 sink via adsorption trapping [Busch et al, 2008;Chareonsuppanimit et al, 2012;Zhang et al, 2012;Kim et al, 2017].…”

Section: 1002/2017gl073532mentioning

confidence: 99%

“…Furthermore, recently, there is a mounting interest in utilizing shale as a CO 2 storage medium itself (whereby CO 2 is injected through fractured horizontal wells), where CO 2 is stored by adsorption trapping [ Fernø et al , ; Li and Elsworth , ; Kim et al ., ] with the benefit of producing additional methane [ Busch et al ., ; Kang et al ., ; Li and Elsworth , ].…”

Section: Introductionmentioning

confidence: 99%

“…However, rock material can be even strongly CO 2 -wet [Arif et al, 2016b;Iglauer et al, 2015a;Iglauer, 2017]-which would massively reduce storage capacity [Al-Menhali et al, 2016;Chaudhary et al, 2013;Iglauer et al, 2015aIglauer et al, , 2015b]-and shale wettability has so far only been reported for low-total organic content (TOC) shales [Chaudhary et al, 2015;Iglauer et al, 2015b;Roshan et al, 2016;Shojai Kaveh et al, 2016] despite the fact that shales can be very rich in organic carbon, i.e., high TOC [Vernik and Milovac, 2011]. Furthermore, recently, there is a mounting interest in utilizing shale as a CO 2 storage medium itself (whereby CO 2 is injected through fractured horizontal wells), where CO 2 is stored by adsorption trapping [Fernø et al, 2015;Li and Elsworth, 2015;Kim et al, 2017] with the benefit of producing additional methane [Busch et al, 2008;Kang et al, 2011;Li and Elsworth, 2015].…”

Section: Introductionmentioning

confidence: 99%

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Influence of shale‐total organic content on CO₂ geo‐storage potential

Arif

Lebedev

Barifcani

et al. 2017

Geophysical Research Letters

128

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Shale CO2 wettability is a key factor which determines the structural trapping capacity of a caprock. However, the influence of shale‐total organic content (TOC) on wettability (and thus on storage potential) has not been evaluated despite the fact that naturally occurring shale formations can vary dramatically in TOC, and that even minute TOC strongly affects storage capacities and containment security. Thus, there is a serious lack of understanding in terms of how shale, with varying organic content, performs in a CO2 geo‐storage context. We demonstrate here that CO2‐wettability scales with shale‐TOC at storage conditions, and we propose that if TOC is low, shale is suitable as a caprock in conventional structural trapping scenarios, while if TOC is ultrahigh to medium, the shale itself is suitable as a storage medium (via adsorption trapping after CO2 injection through fractured horizontal wells).

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Section: 1002/2017gl073532mentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

Influence of shale‐total organic content on CO₂ geo‐storage potential

Arif

Lebedev

Barifcani

et al. 2017

Geophysical Research Letters

128

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“…The adsorption mechanism has been quantitatively analyzed. Kim et al have simulated the Barnett shale gas production with CO 2 huff‐n‐puff by using CMG‐GEM . The effect of reservoir conditions on the gas recovery has been analyzed.…”

Section: Introductionmentioning

confidence: 99%

“…Kim et al have simulated the Barnett shale gas production with CO 2 huff-n-puff by using CMG-GEM. 12 The effect of reservoir conditions on the gas recovery has been analyzed. However, the latest developed gas transport mechanisms in nanoscale have not been considered in their work.…”

Section: Introductionmentioning

confidence: 99%

A review of gas transport and adsorption mechanisms in two‐component methane‐carbon dioxide system

Guo

Sun

et al. 2019

Int J Energy Res

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Summary Injecting carbon dioxide for shale gas recovery enhancement (CO2‐ESGR) is an effective method to improve gas production and also realize the CO2 geosequestration. In the CO2‐ESGR system, there are two‐component gases (TCG) coexisted. The gas transport and adsorption mechanisms are different from the single‐component gas system. However, most of current work is still focused on single‐component gas (ie, methane). Many mechanisms have not been considered in the study of CO2‐ESGR study. In order to conduct reliable numerical simulation for CO2‐ESGR, a clear understanding of the transport and adsorption mechanisms for TCG system is necessary. In this review, we focused on two key issues regarding CO2‐ESGR: the fluid transport and competitive adsorption. The fundamental mechanisms and models for pure gas and TCG transport have been comprehensively summarized. The adsorption models for TCG system have been reviewed and analyzed. Models such as extended Langmuir model, ideal adsorption solution model, and lattice density functional model have been compared. Also, the factors affecting the competitive adsorption of TCG in shale have been illustrated. The main factors include organic matter content, shale composition, pore structure, water content, and pressure. At last, the problems existed in current research of transport and adsorption models for TCG have been analyzed. The issues that are necessary to be considered in CO2‐ESGR technology have been proposed so that more accurate numerical simulation and more reliable production prediction can be achieved.

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