Effect of Interface Structure and Behavior on the Fluid Flow Characteristics and Phase Interaction in the Petroleum Industry: State of the Art Review and Outlook

Hong, Jiajun; Wang, Zhihua; Li, Jinling; Xu, Yunfei; Xin, Hua

doi:10.1021/acs.energyfuels.3c00809

Cited by 44 publications

(18 citation statements)

References 162 publications

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“…Water-based foam is a thermodynamically unstable system, which is manifested in Ostwald ripening, coalescence processes, and gravity-driven drainage . Ostwald ripening is caused by differences in the Laplacian pressure of the bubbles, causing the gas to spread from small to large bubbles.…”

Section: Resultsmentioning

confidence: 99%

“…In addition, XG brings many water-locking structures to the material, such as alcohol hydroxyl and hydrogen bonds, which improve fire extinguishing ability. PF has high viscosity and poor flowability, and the foam could not percolate through the coal pile and cool down Water-based foam is a thermodynamically unstable system, which is manifested in Ostwald ripening, 17 coalescence processes, 19 and gravity-driven drainage. 22 Ostwald ripening is caused by differences in the Laplacian pressure of the bubbles, causing the gas to spread from small to large bubbles.…”

Section: Stability Of Xisfmentioning

confidence: 99%

“…At the same time, it is also found that ISF has problems of poor stability and weak accumulation capacity. Some researchers have tried to improve the stability of ISF by adding materials such as volcanic ash and fibers to cement. , However, this method has very limited stability improvement and cannot fundamentally solve the Ostwald ripening, , coalescence processes, − and gravity-driven drainage − of ISF. It has been shown that the physical and chemical properties of PF determine the size, distribution, and interconnection characteristics of bubbles in ISF .…”

Section: Introductionmentioning

confidence: 99%

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Study on the Preparation of Inorganic Solidified Foam with High Stability and Its Prevention and Treatment of Coal Spontaneous Combustion

Zhao,

Sun,

et al. 2023

Energy Fuels

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In order to prevent coal spontaneous combustion, a highly stable inorganic solidified foam (XISF) suitable for the coal mine top-coal caving region, airtight partition wall, and ″two ends″ of working face was put forward. An ultrastable prefabricated foam (PF) was synthesized by modifying the gas−liquid interface with xanthan gum (XG). The influence of XG content on foam stability was studied by different techniques. In addition, XISF was synthesized by the prefabricated foam method using cement, fly ash, and other noncombustible inorganic materials as the matrix. The stability of PF indicated that the hydrogen bond structure induced by XG could effectively inhibit the Ostwald ripening, coalescence processes, and gravity-driven drainage of the foam. The stability of XISF indicated that when the content of XG was 0−0.3 wt %, the stability of the synthesized XISF increases with the increase of the content of XG. However, when the content of XG was 0.5 wt % (PF system), various active functional groups such as hydroxyl and carboxyl groups in XG chelated with Ca 2+ on the surface of cement particles, forming a ″shell−core″ structure that inhibits hydration. This structure destroys the stability provided by XG. The plugging air leakage test, accumulation diffusion test, and fire extinguishing test show that the improvement of stability was beneficial to improve the fire-preventing and extinguishing characteristic of XISF.

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Section: Resultsmentioning

confidence: 99%

Section: Stability Of Xisfmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

Study on the Preparation of Inorganic Solidified Foam with High Stability and Its Prevention and Treatment of Coal Spontaneous Combustion

Zhao,

Sun,

et al. 2023

Energy Fuels

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“…Three types of salty water and four types of alkanes are prepared: the three brines are distinguished by their salt content of 1.7 g/L LSW, 50 g/L LSW, and 170 g/L HSW, and the four alkanes are pure dodecane, dodecane with SPAN 80, pure heptane, and heptane with SPAN 80. n -Heptane and n -dodecane are selected as the oil phases for verifying the effect of carbon chain lengths. The molecular chain characteristics and group bonding have influence on the water–oil emulsion structure and stability . All oil liquids are equilibrated with high-salinity water for 24 h. To investigate the emulsification effect, we added hydrocarbon-soluble surfactant SPAN 80 to both dodecane and heptane for creating the water-in-oil microemulsions in the oil phase.…”

Section: Microfluidic Experiments Methodologymentioning

confidence: 99%

“…Because of the complicated system of brine/rock/crude oil, many mechanisms may be active and interacting. Hong et al described the various chemical components, e.g., alkalis, surfactants and polymers, play important roles in the interface phenomena of liquid–liquid, gas–liquid, and gas–solid interfaces, which leads to the multiphase fluid flow characteristics and the changes in adsorption behavior of phases. For instance, fine migration is related to the detachment of clay particles and the mineral dissolution.…”

Section: Introductionmentioning

confidence: 99%

Direct Evidence of Salinity Difference Effect on Water Transport in Oil: Pore–Scale Mechanisms

Yan,

Golestan,

Zhou

et al. 2023

Energy Fuels

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Low salinity water flooding is a common technique for enhancing oil recovery; however, the mechanism behind the low-salinity effect, positive or negative, is still not fully understood. In the proposed mechanisms, osmosis and emulsification are considered as two potential reasons for explaining the oil remobilization, but the specific contributions on the remobilization are not well studied at pore-scale. In this article, we performed a series of microfluidic experiments to investigate the movement of constrained oil between invading low-salinity brine and residual high-salinity brine. We find that various salinity contrasts over oil films cause different water fluxes through the oil and swelling areas of the trapped brine, resulting in the relocation of oil phases within the pore spaces. A higher salinity contrast (1.7−170 g/L salt concentrations) provides a faster water penetration in oil phases. In the presence of an oil-soluble surfactant, spontaneous emulsification occurs at the interface of low-salinity brine/oil, which enhances almost 100 times the water flux in two oil phases (nheptane and n-dodecane). We directly observe pore-scale spontaneous emulsification at the low-salinity brine/oil interface but not at the high-salinity brine/oil interface. Furthermore, two scenarios for explaining water transport through the oil phase are proposed: water diffusion due to chemical potential gradient and water transport via reverse micelle or microemulsions movement.

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Study on the microscopic percolation mechanism of different aqueous media huff‐n‐puff with cores in Fengxi tight oil reservoirs of Qinghai Oilfield

Dou,

Yang,

et al. 2024

Energy Science & Engineering

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Huff‐n‐puff (HnF) is a crucial technology for effectively enhancing the oil recovery (EOR) of tight oil reservoirs. Soaking period is the primary platform for injection medium interacting with formation fluid and reservoir rock in HnF. Elucidating the micro‐percolation mechanism of the soaking period is immensely significant for guiding oilfield production practices. The present study established a physical simulation method combining HnF experiments with nuclear magnetic resonance to reveal the microscopic percolation mechanisms, including water, fracturing fluid, and surfactant. Furthermore, the impacts of soaking time, HnF cycles, wettability, and pore structure on oil recovery degree were quantified. The results demonstrate the crucial significance of wettability and pore structure in the soaking period. The dominant mechanism during water HnF in reservoirs characterized by well‐connected pore networks and minimal clay pores is micropore imbibition, while conversely, macropore displacement plays a predominant role. The oil recovery degree of fracturing fluid HnF primarily relies on mitigating solid‐fluid forces within macropores. The surfactant HnF in preferential water‐ and oil‐wet reservoirs is primarily governed by oil films stripped from macropore walls and micropore imbibition, respectively. Specifically, water and fracturing fluid HnF are suitable for shorter soaking time and fewer HnF cycles, whereas the surfactant HnF exhibits an inverse relationship.

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Effect of Interface Structure and Behavior on the Fluid Flow Characteristics and Phase Interaction in the Petroleum Industry: State of the Art Review and Outlook

Cited by 44 publications

References 162 publications

Study on the Preparation of Inorganic Solidified Foam with High Stability and Its Prevention and Treatment of Coal Spontaneous Combustion

Study on the Preparation of Inorganic Solidified Foam with High Stability and Its Prevention and Treatment of Coal Spontaneous Combustion

Direct Evidence of Salinity Difference Effect on Water Transport in Oil: Pore–Scale Mechanisms

Study on the microscopic percolation mechanism of different aqueous media huff‐n‐puff with cores in Fengxi tight oil reservoirs of Qinghai Oilfield

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