Flow behaviors of nitrogen and foams in micro-visual fracture-vuggy structures

Liang, Tuo; Hou, Jirui; Qu, Ming; Song, Chen; Li, Jie; Tan, Tao; Lu, Xinbian; Zheng, Yong

doi:10.1039/d1ra04474e

Cited by 10 publications

(10 citation statements)

References 12 publications

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“…As a result, most attic oil is recovered with the release of pressure. Additionally, compared to the FOI in Figure 7, the GOI always keeps horizontal, corresponding to the discoveries in two-dimensional fracture-vuggy models [29,30,37]. Figure 8d shows a stable OWI and a significant decrease in the GOI with the N 2 cap further expansion.…”

Section: Foam-assisted N2 On Mobilizing Residual Oil Formed From Water Floodingmentioning

confidence: 54%

“…The three-dimensional fracture-vuggy model and actual reservoir are similar in vug and fracture size and injection rates with these similar properties. Consequently, the migration behaviors of the fluids are also similar both in the three-dimensional visualized fracture-vuggy physical model and the actual reservoir [22,30]. The parameters of the three-dimensional visualized fracturevuggy model were calculated based on the three similarity criteria when the similarity criteria index is 1, shown in Table 2.…”

Section: Design Of Three-dimension Visualized Fracture-vuggy Physical Modelmentioning

confidence: 99%

“…Foam cannot form a channeling path due to its low mobility, coating effect on N 2 , and Jamin effect when flows in the fracture-vuggy units [30,37]. The foam accumulation in a fracture-vuggy unit can increase the flow resistance of N 2 and inhibit the N 2 channeling formation, resulting in the increase of sweep efficiency [30]. This accumulation behavior in the top of a fracture-vuggy unit can also suppress the rise of bottom water.…”

Section: Synergistic Effects Of Foam-assisted N 2 and Bottom Water On Interface Evolutionmentioning

confidence: 99%

“…The FOI away from the injection well is higher than that close to the injection well. The N 2 with a lower flow resistance can evenly accumulate in the top of the fracture-vuggy unit, while the N 2 foam with a higher migration resistance preferentially accumulates in the top of the fracture-vuggy unit close to the injection well [29,30]. With the foam injection, the N 2 foam accumulates in the whole top of the vug, generating a downward-driven force.…”

Section: Synergistic Effects Of Foam-assisted N 2 and Bottom Water On Interface Evolutionmentioning

confidence: 99%

“…The foam-polymer flooding method was also proposed to significantly enhance oil recovery in reservoirs [28]. Recent years, the foam-assisted N 2 flooding method, a combination of foam and nitrogen gas flooding, has attracted considerable attention to increase crude oil production [29,30]. Foam with low mobility can virtually plug the high permeable channel [31,32].…”

Section: Introductionmentioning

confidence: 99%

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Study on Fluid Behaviors of Foam-Assisted Nitrogen Flooding on a Three-Dimensional Visualized Fracture–Vuggy Model

Liang

Hou

2021

Applied Sciences

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Tahe Oilfield, located in northwest China, is an unconventional fracture–vuggy carbonate reservoir. The foam-assisted nitrogen gas flooding technology has been proven to be a potential EOR technology. However, the flow behaviors of foam-assisted nitrogen gas in fracture–vuggy structures are not clear due to the complex fracture–vuggy structures and their strong heterogeneity. In this work, a three-dimensional visualized fracture–vuggy model is designed and fabricated to investigate the fluids behaviors of foam-assisted N2 flooding and classify the residual oil types after foam-assisted N2 flooding. Experimental results reveal that foam slug can enlarge the sweep efficiency, suppress the formation of nitrogen gas channeling, and detach the oil film. Additionally, the evolution processes of the gas–oil and oil–water interfaces are investigated and analyzed. Moreover, the residual oil types after foam-assisted N2 flooding and nitrogen gas flooding, respectively, are classified and summarized. Compared to nitrogen gas flooding after water flooding, 12.36% more oil can be recovered through foam-assisted N2 flooding. This work further studies the fluid flow behaviors of foam-assisted N2 in the three-dimensional visualized fracture–vuggy carbonate model and also confirms the previous achievements.

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Section: Foam-assisted N2 On Mobilizing Residual Oil Formed From Water Floodingmentioning

confidence: 54%

Section: Design Of Three-dimension Visualized Fracture-vuggy Physical Modelmentioning

confidence: 99%

Section: Synergistic Effects Of Foam-assisted N 2 and Bottom Water On Interface Evolutionmentioning

confidence: 99%

Section: Synergistic Effects Of Foam-assisted N 2 and Bottom Water On Interface Evolutionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Study on Fluid Behaviors of Foam-Assisted Nitrogen Flooding on a Three-Dimensional Visualized Fracture–Vuggy Model

Liang

Hou

2021

Applied Sciences

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The development of heat‐resistant and salt‐tolerant foam with betaine surfactants

Zhang

Guo

et al. 2022

J Surfact & Detergents

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A modified instrument was designed to evaluate foam properties under high temperature and pressure. The type and molar ratio of betaine surfactants were screened to develop the heat-resistant and salt-tolerant foam for Tahe oilfield (130 C, 220 g/L), and the effects of temperature and pressure on foam properties were also investigated. The synergism between surfactants and the enhanced oil recovery (EOR) mechanism of foam flooding in fractured-vuggy reservoirs were studied. Experimental results showed the developed foam had excellent foaming ability and foam stability when the lauramidopropyl hydroxyl sulfobetaine (LHSB): erucic amide propyl betaine (EAB) molar ratio ranged from 1:1 to 1:2 (initial foam volume was 392 ml when the molar ratio was 1:1, drainage half-time was 5.75 min and foam half-time was 72 min when the molar ratio was 1:2 at 130 C and 2 MPa). The synergistic effect was found to reach its maximum when the LHSB:EAB molar ratio ranged from 1:1 to 1:2 according to interaction parameters, which agreed with the results of foam properties. Foam stability was found to considerably increase with increasing pressure, but decrease with increasing temperature. However, temperature and pressure were found to have consistent effects on foaming ability, that is, the foaming ability increased with increasing temperature and pressure. The flooding test showed foam flooding exhibited better sweep efficiency and higher recovery ratio in the fractured-vuggy model than gas flooding and water flooding. This could be because injected foam did not channel through the top (or bottom) path due to its high viscosity and moderate density.

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Underground hydrogen storage in reservoirs: pore-scale mechanisms and optimization of storage capacity and efficiency

et al. 2023

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Flow behaviors of nitrogen and foams in micro-visual fracture-vuggy structures

Abstract: Nitrogen gas flooding and foam flooding have been widely used for oil and gas development in fracture-vuggy carbonate reservoirs.

Cited by 10 publications

References 12 publications

Study on Fluid Behaviors of Foam-Assisted Nitrogen Flooding on a Three-Dimensional Visualized Fracture–Vuggy Model

Study on Fluid Behaviors of Foam-Assisted Nitrogen Flooding on a Three-Dimensional Visualized Fracture–Vuggy Model

The development of heat‐resistant and salt‐tolerant foam with betaine surfactants

Underground hydrogen storage in reservoirs: pore-scale mechanisms and optimization of storage capacity and efficiency

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