Interfacial tension for CO2/CH4/brine systems under reservoir conditions

Liu, Yueliang; Rui, Zhenhua

doi:10.1016/b978-0-323-91660-8.00008-7

Cited by 2 publications

(2 citation statements)

References 71 publications

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“…Compared with the values of 0.12 g/cm 3 for methane and 0.98 g/cm 3 for water given by the National Institute of Standards and Technology (NIST), the absolute standard deviations from the NIST are 8.33 and 2.97%, respectively. The obtained IFT is 54.95 mN/m, consistent with the experimental result of 56.43 mN/m from Liu et al 19 The simulation results show that our methodology and model are reliable.…”

Section: Resultssupporting

confidence: 89%

Resonance-Induced Reduction of Interfacial Tension of Water–Methane and Improvement of Methane Solubility in Water

Pan

Liu

et al. 2022

Langmuir

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Molecular dynamics simulations were performed to study the effect of the periodic oscillating electric field on the interface between water and methane. We propose a new strategy that utilizes oscillating electric fields to reduce the interfacial tension (IFT) between water and methane and increase the solubility of methane in water simultaneously. These are attributed to the hydrogen bond resonance induced by an electric field with a frequency close to the natural frequency of the hydrogen bond. The resonance breaks the hydrogen bond network among water molecules to the maximum, which destroys the hydration shell and reduces the cohesive action of water, thus resulting in the decrease of IFT and the increase of methane solubility. As the frequency of the electric field is close to the optimum resonant frequency of hydrogen bonds, IFT decreases from 56.43 to 5.66 mN/m; water and methane are miscible because the solubility parameter of water reduces from 47.63 to 2.85 MPa1/2, which is close to that of methane (3.43 MPa1/2). Our results provide a new idea for reducing the water–gas IFT and improving the solubility of insoluble gas in water and theoretical guidance in the fields of natural gas exploitation, hydrate generation, and nanobubble nucleation.

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Section: Resultssupporting

confidence: 89%

Resonance-Induced Reduction of Interfacial Tension of Water–Methane and Improvement of Methane Solubility in Water

Pan

Liu

et al. 2022

Langmuir

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“…7−10 In conventional reservoirs, the main mechanisms of CO 2 injection to EOR are pressure maintenance, reducing crude oil viscosity, extracting light components, and reducing the IFT. 11,12 The fracture with high conductivity in the shale reservoir will affect the CO 2 injection development result. 13 As the focus gradually shifts from the conventional reservoir to the unconventional reservoir and the difficulty of CO 2 injection increases, researchers proposed an innovative injection method of CO 2 huff-n-puff (HNP).…”

Section: Introductionmentioning

confidence: 99%

Diffusion Effect on Shale Oil Recovery by CO₂ Huff-n-Puff

Peng

Sheng

2023

Energy Fuels

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The CO 2 diffusion effect is an important mechanism of injected CO 2 penetrating the reservoir matrix and diffusing into the oil phase during the huff-n-puff (HNP) process. However, the CO 2 diffusion coefficient of shale is still uncertain under the reservoir conditions, and the contribution of diffusion to enhanced oil recovery (EOR) needs to be further explored. In this study, the CO 2 diffusion coefficient of shale is determined under the simulated reservoir conditions (9−10 MPa, 90 °C) in the laboratory, and the determined CO 2 diffusion coefficient is applied in the reservoir numerical model to evaluate the contribution of the CO 2 diffusion effect to EOR in the HNP process. First, a radial constant volume diffusion (RCVD) device was built to measure the CO 2 diffusion coefficient by the pressure decay method. After that, both the analytical solution and the numerical solution are used to ensure that the result is correct. Finally, a field-scale model consisting of one stage of hydraulic fracture in a shale oil reservoir is established. The effects of reservoir properties such as fracture spacing, fracture half-length, and operational properties of HNP like injection rate, injection time, and soaking time on oil recovery were discussed when the diffusion was included and excluded. The CO 2 diffusion coefficient of a shale core is ranging from 1.44 × 10 −7 to 5.50 × 10 −7 cm 2 /s, and it is reasonable to be applied in the field reservoir numerical simulation model. According to simulation results, the lower fracture spacing and longer fracture half-length make more CO 2 diffuse into the shale matrix, which are critical parameters, to promote the CO 2 diffusion effect. When the injection rate is slow and the injection time is short, the CO 2 diffusion effect in the reservoir may contribute more to EOR. A high injection rate means sufficient pressure supplement, and the CO 2 diffusion effect may become relatively negligible. The soaking time may not be necessary for the EOR of HNP, but the longer soaking time will promote the contribution of CO 2 diffusion to EOR, and the incremental recovery is about 0.15−0.26%.

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Interfacial tension for CO2/CH4/brine systems under reservoir conditions

Cited by 2 publications

References 71 publications

Resonance-Induced Reduction of Interfacial Tension of Water–Methane and Improvement of Methane Solubility in Water

Resonance-Induced Reduction of Interfacial Tension of Water–Methane and Improvement of Methane Solubility in Water

Diffusion Effect on Shale Oil Recovery by CO₂ Huff-n-Puff

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Interfacial tension for CO2/CH4/brine systems under reservoir conditions

Cited by 2 publications

References 71 publications

Resonance-Induced Reduction of Interfacial Tension of Water–Methane and Improvement of Methane Solubility in Water

Resonance-Induced Reduction of Interfacial Tension of Water–Methane and Improvement of Methane Solubility in Water

Diffusion Effect on Shale Oil Recovery by CO2 Huff-n-Puff

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Diffusion Effect on Shale Oil Recovery by CO₂ Huff-n-Puff