Mathematical model of the spontaneous imbibition of water into oil-saturated fractured porous media with gravity

Cheng, Hui; Wang, Fuyong

doi:10.1016/j.ces.2020.116317

Cited by 14 publications

(11 citation statements)

References 32 publications

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“…The number and aperture of curved capillary tube bundles conform to the fractal scaling law. Based on fractal theory, − the scale of the imbibition models is upgraded.…”

Section: Imbibition Model Of Fractal Porous Mediamentioning

confidence: 99%

Mathematical Model and Application of Spontaneous and Forced Imbibition in Shale Porous Media-Considered Forced Pressure and Osmosis

Wang

et al. 2022

Energy Fuels

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The energized hydraulic fracturing technology of “energizing, hydraulic fracturing, shut-in, and flowback” has achieved good development results in some shale oil fields. The mechanisms of forced imbibition (FI) under forced pressure (the difference between hydraulic fluid pressure and original pore pressure) need to be further studied; especially, the difference and boundary of various mechanisms in forced soaking are still unclear. The wettability of pores is different, the reservoir shows strong mixed wettability, and the permeability of clay mineral pores has osmotic pressure. This paper analyzes the imbibition forces in distinct types of pores, and the dynamic models of spontaneous imbibition (SI) and FI in a single capillary tube are established. Based on the fractal theory and capillary bundle model, the mathematical models of SI and FI at the core scale are established, and semi-analytical solution models considering different forces are proposed, especially considering forced pressure and osmosis. In addition, the above mathematical models are fitted and verified by imbibition experiments and NMR, which ensured the accuracy and validity of the mathematical models. In this paper, the sensitivity analysis of different factors to oil displacement rate and oil recovery by imbibition is quantitatively evaluated. The research shows that the imbibition rate of FI is faster than that of SI, and the ultimate oil recovery is also higher. Smaller pores mainly control the imbibition rate, which increases with oil–water interfacial tension and forced pressure. However, the imbibition rate decreases with increasing water-phase viscosity and fractal dimension.

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“…The number and aperture of curved capillary tube bundles conform to the fractal scaling law. Based on fractal theory, − the scale of the imbibition models is upgraded.…”

Section: Imbibition Model Of Fractal Porous Mediamentioning

confidence: 99%

Mathematical Model and Application of Spontaneous and Forced Imbibition in Shale Porous Media-Considered Forced Pressure and Osmosis

Wang

et al. 2022

Energy Fuels

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“…Imbibition occurs under the action of the capillary force, which cannot be ignored in tight reservoirs [31]. In the imbibition process, the capillary force supplies the power to replace the oil in the secondary and tertiary pores with the water in the primary pores [32]. This process is shown in Figure 12.…”

Section: Imbibition Modelmentioning

confidence: 99%

Division Method and Seepage Law of Seepage Channels in a Tight Reservoir

Fang

et al. 2021

Geofluids

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Tight oil reservoirs are characterized by a low porosity, low permeability, and strong heterogeneity. The macropores, throats, and microcracks in reservoirs are the main seepage channels, which affect the seepage law in the reservoirs. In particular, oil-water two-phase flow in different types of pores requires further study. In this study, two groups of online NMR displacement experiments were designed to study the seepage characteristics of tight oil reservoirs. It was found that the main seepage channels for oil-water two-phase flow are the microcracks, large pores, and throats in the reservoir. The large pores are mainly micron and submicron scale in size. The oil in the small pores is only transferred to the large pores through imbibition to participate in the flow, and there is no two-phase flow. Based on the influence of different pore structures on the seepage law of a tight reservoir, the pores were divided into seepage zones, and a multistage seepage model for tight reservoirs was established. Based on this model, the effects of the imbibition, stress sensitivity, threshold pressure gradient, and Jamin effect on model’s yield were studied. The results show that imbibition is no longer effective after a while. Owing to the stress sensitivity, the threshold pressure gradient, and the Jamin effect, oil production will be reduced. As the parameter value increases, the oil production decreases. The production decreases rapidly in the early stage of mining while decreases slowly in the later stage, exhibiting a trend of high yield in the early stage and stable yield in the later stage.

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“…Yang et al 33 experientially studied the effect of fracture distribution on surfactant-enhanced spontaneous imbibition in fractured tight oil reservoirs. Different mathematical models were also proposed to model the process of spontaneous imbibition in the tight oil reservoir, and the effects of pore size distribution, 34 displacement pressure gradient, 35 gravity, 36 and buoyancy on imbibition were revealed in our previous study.…”

Section: Introductionmentioning

confidence: 99%

Experimental Mechanism for Enhancing Oil Recovery by Spontaneous Imbibition with Surfactants in a Tight Sandstone Oil Reservoir

Wang

Liang

et al. 2023

Energy Fuels

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This study aims to investigate the mechanism behind surfactant enhanced oil recovery under reservoir conditions through experiments on spontaneous imbibition with surfactants. The tight sandstone samples are characterized using cast thin section (CTS), high-pressure mercury intrusion (HPMI), and nuclear magnetic resonance (NMR) to determine their clay mineral composition, pore size distribution, and fluid distribution. Spontaneous imbibition experiments are then conducted using formation water and surfactant solutions as imbibition liquids, with three different types of surfactantsdodecylbenzene sulfonate (DBS), sodium dodecyl sulfate (SDS), and ammonium bromideat two different concentrations, each to examine the effect of surfactant type. Additionally, the interfacial tension (IFT) between crude oil and different imbibition solutions is measured, and the contact angles of an oil droplet on the core surface in air, formation water, distilled water, and surfactant solution are determined. Finally, the effects of IFT, rock wettability, formation water salinity, and core permeability on final oil recovery by spontaneous imbibition are analyzed. The results indicate that surfactant-assisted spontaneous imbibition primarily operates through IFT reduction, wettability alteration, and emulsification of crude oil. However, ultralow IFT may lead to low ultimate oil recovery. To increase the ultimate oil recovery of spontaneous imbibition, reducing the salinity of the surfactant solution and creating microfractures can be effective strategies.

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Mathematical model of the spontaneous imbibition of water into oil-saturated fractured porous media with gravity

Cited by 14 publications

References 32 publications

Mathematical Model and Application of Spontaneous and Forced Imbibition in Shale Porous Media-Considered Forced Pressure and Osmosis

Mathematical Model and Application of Spontaneous and Forced Imbibition in Shale Porous Media-Considered Forced Pressure and Osmosis

Division Method and Seepage Law of Seepage Channels in a Tight Reservoir

Experimental Mechanism for Enhancing Oil Recovery by Spontaneous Imbibition with Surfactants in a Tight Sandstone Oil Reservoir

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