The impact of supercritical CO2 exposure time on the effective stress law for permeability in shale

Tian, Shifeng; Zhou, Junping; Xian, Xuefu; Gan, Quan; Zhang, Chengpeng; Dong, Zhiqiang; Kuang, Nianjie

doi:10.1016/j.energy.2023.129334

Cited by 10 publications

(1 citation statement)

References 47 publications

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“…The hydrocarbons in low-maturity oil shales comprise already formed petroleum, bituminous substances, and solid organic matter without undergoing thermal degradation. − Accordingly, an in situ heating strategy is introduced as an approach to enable the immobile content (e.g., heavy oil, bitumen, and undegraded kerogen) in low-maturity oil shales to be transformed into mobile light oil (and gas). ,− This in situ heating operation is conducted with a thermal source (like electrical heating and water vapor) injected into a shale reservoir, − allowing the heat conduction behavior to pyrolyze the low-maturity shale oil in the area close to heating the injection well. , To wit, the in situ thermally upgraded area is largely determined by the thermophysical performance of low-maturity oil shales, which further identifies the oil production capacity as well as the potential economic efficiency.…”

Section: Introductionmentioning

confidence: 99%

Evolution of the Anisotropic Thermophysical Performance for Low-Maturity Oil Shales at an Elevated Temperature and Its Implications for Restoring Oil Development

Bai,

Li,

Liu

et al. 2024

Energy Fuels

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Thermophysical properties determine the thermally upgraded area of low-maturity oil shales, which is of significance for restoring oil recovery but needs more in-depth investigations. We introduced a laser-flash NETZSCH LFA-467 analyzer to measure the dynamic response of thermal diffusivity (D), thermal conductivity (K), and specific heat capacity (c) at an in situ elevated temperature as well as their anisotropy in the orthogonal direction relative to shale bedding. The D and K values decrease with a rising temperature, while c values remain almost unchanged at a high temperature. The total organic carbon (TOC) content significantly affects the D and K values, mainly in the anisotropy coefficient (a newly proposed parameter), but sparingly influences the c values. The anisotropy coefficient of samples with a high TOC content is ∼2 times greater than that with a low TOC content. The greatest D value decay rate of a high TOC content sample reaches ∼75%, while that for a low TOC content sample is ∼43%, found in the bedding-perpendicular samples. Results also suggest that the anisotropy of the thermophysical property derives from the lamellar structure of shale rock; the space (like pore and/or fracture) therein is averse to the heat movement. For the hypothetical vertical well mode or horizontal well mode, the arrangement of reasonable space between wells of heat injection and restoring oil production is of significance under the heating-induced dynamic evolution of thermophysical parameters. Hopefully, this work is helpful in enhancing the knowledge on the heat flow behavior in low-maturity oil shale when thermal upgrading is implemented.

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Section: Introductionmentioning

confidence: 99%

Evolution of the Anisotropic Thermophysical Performance for Low-Maturity Oil Shales at an Elevated Temperature and Its Implications for Restoring Oil Development

Bai,

Li,

Liu

et al. 2024

Energy Fuels

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Microscale heat and mass transfer characteristics of CO₂ flooding in nanotubes of tight oil reservoirs

Wang

2024

Can J Chem Eng

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The mechanism of heat and mass transfer in tight oil reservoirs after CO2 injection is complex. In this paper, first, a CO2 transfer model within microscale adjacent nanotubes in tight oil reservoirs is established. Then, the typical heat and mass transfer characteristics of microscale CO2 in tight oil reservoirs is analyzed, and the influence of grid density on the calculation results is discussed. Finally, the influence of thermal conductivity of tight oil reservoirs on CO2 physical properties parameters is revealed. Results show that: (a) From the inlet end of the thick nanotube to the outlet of the nanotube, the pressure of CO2 drops from 3.5 to 3.3697 MPa. (b) When the mesh length is equal to 5 nm, the CO2 pressure in the thin nanotube drops from 3.5 to 3.3329 MPa, and the CO2 pressure in the thick nanotube drops from 3.5 to 3.2018 MPa. (c) Organic amines react with CO2 to form salts, which can seal high permeability layers and cracks, but there is a risk of environmental pollution.

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Effects of CO2-saturated brine imbibition on the mechanical and seepage characteristics of Longmaxi shale

Lyu,

Deng,

Tan

et al. 2024

Energy

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The impact of supercritical CO2 exposure time on the effective stress law for permeability in shale

Cited by 10 publications

References 47 publications

Evolution of the Anisotropic Thermophysical Performance for Low-Maturity Oil Shales at an Elevated Temperature and Its Implications for Restoring Oil Development

Evolution of the Anisotropic Thermophysical Performance for Low-Maturity Oil Shales at an Elevated Temperature and Its Implications for Restoring Oil Development

Microscale heat and mass transfer characteristics of CO₂ flooding in nanotubes of tight oil reservoirs

Effects of CO2-saturated brine imbibition on the mechanical and seepage characteristics of Longmaxi shale

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The impact of supercritical CO2 exposure time on the effective stress law for permeability in shale

Cited by 10 publications

References 47 publications

Evolution of the Anisotropic Thermophysical Performance for Low-Maturity Oil Shales at an Elevated Temperature and Its Implications for Restoring Oil Development

Evolution of the Anisotropic Thermophysical Performance for Low-Maturity Oil Shales at an Elevated Temperature and Its Implications for Restoring Oil Development

Microscale heat and mass transfer characteristics of CO2 flooding in nanotubes of tight oil reservoirs

Effects of CO2-saturated brine imbibition on the mechanical and seepage characteristics of Longmaxi shale

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Product

Resources

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Microscale heat and mass transfer characteristics of CO₂ flooding in nanotubes of tight oil reservoirs