Techno-economic assessment of industrial CO2 storage in depleted shale gas reservoirs

Tayari, Farid; Blumsack, Seth; Dilmore, Robert; Mohaghegh, Shahab D.

doi:10.1016/j.juogr.2015.05.001

Cited by 23 publications

(8 citation statements)

References 24 publications

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“…As such, CO 2 injected into a partially depleted hydrocarbon-bearing shale could be expected to displace methane from adsorption sites, allowing it to desorb and be recovered (Godec et al, 2013b;Kulga et al, 2014). The potential to use existing wells for CO 2 injection to help recover additional hydrocarbons would offset some of the costs associated with CCS, potentially providing an economic advantage to storage in partially depleted hydrocarbon-bearing shales compared to CCS in deep saline formations (Nuttall et al, 2005;Kang et al, 2011;Wang et al, 2011;Chareonsuppanimit et al, 2012;Godec et al, 2013a,b;Tao and Clarens, 2013;Tayari et al, 2015).…”

Section: Carbon Storage In Shale: Advantages and Disadvantagesmentioning

confidence: 99%

“…These include cost savings from detailed, prior site characterization, the ability to utilize existing infrastructure including wells, well pads, and surface pipeline rights of way, and the potential for enhanced hydrocarbon production from CO 2 injection (Tayari et al, 2015). However, the primary advantage is expected to be the existence of a large induced hydraulic fracture network from previous hydrocarbon production.…”

Section: Carbon Storage In Shale: Advantages and Disadvantagesmentioning

confidence: 99%

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U.S. DOE NETL methodology for estimating the prospective CO2 storage resource of shales at the national and regional scale

Levine

Fukai

Soeder

et al. 2016

International Journal of Greenhouse Gas Control

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a b s t r a c tWhile the majority of shale formations will serve as reservoir seals for stored anthropogenic carbon dioxide (CO 2 ), hydrocarbon-bearing shale formations may be potential geologic sinks after depletion through primary production. Here we present the United States-Department of Energy-National Energy Technology Laboratory (US-DOE-NETL) methodology for screening-level assessment of prospective CO 2 storage resources in shale using a volumetric equation. Volumetric resource estimates are produced from the bulk volume, porosity, and sorptivity of the shale and storage efficiency factors based on formationscale properties and petrophysical limitations on fluid transport. Prospective shale formations require: (1) prior hydrocarbon production using horizontal drilling and stimulation via staged, high-volume hydraulic fracturing, (2) depths sufficient to maintain CO 2 in a supercritical state, generally >800 m, and (3) an overlying seal. The US-DOE-NETL methodology accounts for storage of CO 2 in shale as a free fluid phase within fractures and matrix pores and as an sorbed phase on organic matter and clays. Uncertainties include but are not limited to poorly-constrained geologic variability in formation thickness, porosity, existing fluid content, organic richness, and mineralogy. Knowledge of how these parameters may be linked to depositional environments, facies, and diagenetic history of the shale will improve the understanding of pore-to-reservoir scale behavior, and provide improved estimates of prospective CO 2 storage.Published by Elsevier Ltd.

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Section: Carbon Storage In Shale: Advantages and Disadvantagesmentioning

confidence: 99%

Section: Carbon Storage In Shale: Advantages and Disadvantagesmentioning

confidence: 99%

U.S. DOE NETL methodology for estimating the prospective CO2 storage resource of shales at the national and regional scale

Levine

Fukai

Soeder

et al. 2016

International Journal of Greenhouse Gas Control

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“…The costs of CO 2 injection and transportation are dominant factors affecting the economic viability of CCS in shales. These costs are controlled by the potential revenue form CH 4 production and other factors including well spacing, CO 2 separation, and bottom-hole pressure [129]. The CO 2 injection cost is related directly to the CO 2 injectivity approach used, i.e., the applied huff-n-puff processes in the Big Sinking Field showed an increase in injection cost by USD 0.35/metric tonnes [130].…”

Section: Economic Viability Of Ccs In Shalesmentioning

confidence: 99%

“…However, the added cost of CO 2 transportation is large compared to injection and capture costs. A study [129] on Marcellus shales estimated a cost of USD 60-70/metric tonnes to transport CO 2 from industrial source to the site, added to the USD 22.4/metric cost of for CO 2 injection. These results indicate that using shorter pipeline transport distances with smaller diameters could be a suitable method to reduce the transport cost, which eventually implies high incremental capital costs.…”

Section: Economic Viability Of Ccs In Shalesmentioning

confidence: 99%

A Review on the Influence of CO2/Shale Interaction on Shale Properties: Implications of CCS in Shales

et al. 2020

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Carbon capture and storage (CCS) is a developed technology to minimize CO2 emissions and reduce global climate change. Currently, shale gas formations are considered as a suitable target for CO2 sequestration projects predominantly due to their wide availability. Compared to conventional geological formations including saline aquifers and coal seams, depleted shale formations provide larger storage potential due to the high adsorption capacity of CO2 compared to methane in the shale formation. However, the injected CO2 causes possible geochemical interactions with the shale formation during storage applications and CO2 enhanced shale gas recovery (ESGR) processes. The CO2/shale interaction is a key factor for the efficiency of CO2 storage in shale formations, as it can significantly alter the shale properties. The formation of carbonic acid from CO2 dissolution is the main cause for the alterations in the physical, chemical and mechanical properties of the shale, which in return affects the storage capacity, pore properties, and fluid transport. Therefore, in this paper, the effect of CO2 exposure on shale properties is comprehensively reviewed, to gain an in-depth understanding of the impact of CO2/shale interaction on shale properties. This paper reviews the current knowledge of the CO2/shale interactions and describes the results achieved to date. The pore structure is one of the most affected properties by CO2/shale interactions; several scholars indicated that the differences in mineral composition for shales would result in wide variations in pore structure system. A noticeable reduction in specific surface area of shales was observed after CO2 treatment, which in the long-term could decrease CO2 adsorption capacity, affecting the CO2 storage efficiency. Other factors including shale sedimentary, pressure and temperature can also alter the pore system and decrease the shale “caprock” seal efficiency. Similarly, the alteration in shales’ surface chemistry and functional species after CO2 treatment may increase the adsorption capacity of CO2, impacting the overall storage potential in shales. Furthermore, the injection of CO2 into shales may also influence the wetting behavior. Surface wettability is mainly affected by the presented minerals in shale, and less affected by brine salinity, temperature, organic content, and thermal maturity. Mainly, shales have strong water-wetting behavior in the presence of hydrocarbons, however, the alteration in shale’s wettability towards CO2-wet will significantly minimize CO2 storage capacities, and affect the sealing efficiency of caprock. The CO2/shale interactions were also found to cause noticeable degradation in shales’ mechanical properties. CO2 injection can weaken shale, decrease its brittleness and increases its plasticity and toughness. Various reductions in tri-axial compressive strength, tensile strength, and the elastic modulus of shales were observed after CO2 injection, due to the dissolution effect and adsorption strain within the pores. Based on this review, we conclude that CO2/shale interaction is a significant factor for the efficiency of CCS. However, due to the heterogeneity of shales, further studies are needed to include various shale formations and identify how different shales’ mineralogy could affect the CO2 storage capacity in the long-term.

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“…As lacunas ou incertezas de Custos de injeção (dólares/tCO regulação para atividades de CCS também contribuem para a dificuldade de avaliação de custos, como por exemplo a atribuição de responsabilidade, o tempo e as exigências de monitoramento do CO2 injetado. As abordagens metodológicas diferem na abrangência do processo de injeção (consideração de custos de captura e de monitoramento), dos valores de cada componente, de parâmetros econômicos, do aproveitamento de infraestrutura existente, do aprofundamento das características dos reservatórios, entre outros (Bielicki et al, 2018;Davidson et al, 2014;Jiang et al, 2019;Kwak e Kim, 2017;Pei et al, 2015;Tayari et al, 2015;Wei et al, 2015;Welkenhuysen, 2018). Os custos na literatura para esse tipo de projeto chegam a variar de cerca de 20 a mais de 180 dólares por tonelada de CO2 injetado.…”

Section: Resultsunclassified

Armazenamento geológico de carbono em reservatórios não convencionais na Formação Irati da Bacia do Paraná: estimativas de capacidade de injeção de CO2 e custos associados

Masulino¹

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Techno-economic assessment of industrial CO2 storage in depleted shale gas reservoirs

Cited by 23 publications

References 24 publications

U.S. DOE NETL methodology for estimating the prospective CO2 storage resource of shales at the national and regional scale

U.S. DOE NETL methodology for estimating the prospective CO2 storage resource of shales at the national and regional scale

A Review on the Influence of CO2/Shale Interaction on Shale Properties: Implications of CCS in Shales

Armazenamento geológico de carbono em reservatórios não convencionais na Formação Irati da Bacia do Paraná: estimativas de capacidade de injeção de CO2 e custos associados

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