Advances in enhanced oil recovery technologies for low permeability reservoirs

Kang, Wanli; Zhou, Bobo; Issakhov, Miras; Gabdullin, Marabek

doi:10.1016/j.petsci.2022.06.010

Cited by 103 publications

(40 citation statements)

References 199 publications

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“…On this basis, the research direction of developing low permeability reservoirs by CO 2 injection in China is further proposed, which provides technical reference and guidance for the implementation of CO 2 flooding in China. In view of tight matrix, complex fracture system, low production level of oil wells, low recovery factor and poor development effect in low permeability reservoirs, Wang et al elaborated the application characteristics and adaptability of six EOR technologies, such as improving water drive, gas drive, chemical drive, etc., and defined the basis for promoting the progress of EOR technology in low permeability reservoirs and the research direction of EOR technology [2]. According to the characteristics of low porosity, low permeability and/or low saturation of complex oil and gas reservoirs, He et al analyzed the limitations of conventional logging in such reservoirs, and put forward corresponding new logging theories and methods [3].…”

Section: Introductionmentioning

confidence: 99%

Pilot Test for Nitrogen Foam Flooding in Low Permeability Reservoir

Zhou¹,

Jia²,

Qian³

et al. 2023

Energy Engineering

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Due to the characteristics of reservoir formation, the producing level of low permeability reservoir is relatively very low. It is hard to obtain high recovery through conventional development schemes. Considering the tight matrix, complex fracture system, low production level of producers, and low recovery factor of M block in Xinjiang oilfield, it is selected for on-site pilot test of nitrogen foam flooding. Detailed flooding scheme is made and the test results are evaluated respectively both for producers and injectors. The pressure index, filling degree, and fluid injection profile are found to be all improved in injectors after injection of nitrogen foam. The oil production, water cut and liquid production file are also improved in most of the producers, with the natural decline rate in the test area become slow. Results show that nitrogen foam flooding technology can be good technical storage for enhanced oil recovery in low permeability reservoir.

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Section: Introductionmentioning

confidence: 99%

Pilot Test for Nitrogen Foam Flooding in Low Permeability Reservoir

Zhou¹,

Jia²,

Qian³

et al. 2023

Energy Engineering

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“…Because of the extreme low permeability, hydraulic fracturing technology has been applied to create seepage channels for reservoirs and improve the flow capacity of injected fluids, significantly increasing the production of a single-well fluid. − After that, gas can be injected into the formation to replenish the formation energy and enhance oil recovery. However, because of the complex fracture system, gas breakthrough channels can easily form and only a 10% final recovery can be achieved owing to the low mobility control ability of the injected gas phase. − …”

Section: Introductionmentioning

confidence: 99%

Dynamic Features of Nonaqueous Foam in Fracture Systems

Zhao

et al. 2023

Energy Fuels

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The use of foam as a fluid for gas mobility control has become increasingly popular due to its effectiveness. However, the destabilization of aqueous foam by oil has led to a growing interest in nonaqueous foam. Despite this, there have been limited studies on the dynamic features of nonaqueous foam in fractures. In this study, we investigate the impact of roughness and fracture width on the flow behavior of non-aqueous foam using both microscopic visualization and macroscopic core flooding techniques. We also uncover the regeneration and regulation mechanisms of non-aqueous foam, while establishing a control group of aqueous foam for comparative purposes. Our experimental results show that as the roughness of the fracture increases, the pressure difference generated by both foams also increases, but decreases as the fracture width increases. Moreover, the optimal gas–liquid ratio for aqueous foam is 2:1, while that of nonaqueous foam is 1:2. Nonaqueous foam tends to be captured and deformed when transported through rough fracture surfaces. This deformation causes necking separation, which eventually leads to the generation of new foam. Furthermore, roughness anchors the foam, prolonging its stay in the fracture and increasing seepage resistance. The presence of kerosene in the fractured shale core reduces the stability of nonaqueous foam, as evidenced by a ∼23.3% decrease in differential pressure.

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“…Compared to other reservoirs, low-permeability reservoirs face the problems of high injection pressure and difficult injection. Low-permeability reservoirs have small pores and throats, poor connectivity, huge specific surface area, large thickness of boundary layer between crude oil and rock, strong heterogeneity, and many microfractures . In the development of a low-permeability reservoir, long-term water injection makes rock surfaces strongly hydrophilic.…”

Section: Introductionmentioning

confidence: 99%

“…Low-permeability reservoirs have small pores and throats, poor connectivity, huge specific surface area, large thickness of boundary layer between crude oil and rock, strong heterogeneity, and many microfractures. 1 In the development of a low-permeability reservoir, long-term water injection makes rock surfaces strongly hydrophilic. The adhesion resistance of the fluid in the porous medium increases, forming water boundary layers, 2 reducing permeability, increasing water injection pressure, 3 and ultimately hindering injection and reducing oil recovery.…”

Section: Introductionmentioning

confidence: 99%

Preparation of SiO₂-Fluorinated Acrylate Polymer Nanoemulsions (SCFs) and Their Application as Depressurization and Injection Treatment Agents

Qiao

et al. 2022

Energy Fuels

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For water injection development in low-permeability reservoirs, nanoscale SiO2-fluorinated acrylate polymer nanoemulsions (SCFs) with good properties were prepared through core–shell emulsion polymerization. The results show that nano-SiO2 particles are well dispersed, the average particle size of the SCFs is 113 nm, and the synergy among fluoride chain segments is good and effectively improves the utilization of fluorine atoms. SCFs form a low-surface-energy nanoscale hydrophobic film on the rock surface, which changes the original rock surface micro- or nanostructure, resulting in a water contact angle of up to 120° at the core. At 60 °C, the interfacial tension (IFT) between a 1500 mg/L SCF dispersion and white mineral oil is 1.86 mN/m, decreasing by 95.67% relative to the oil–water IFT at room temperature. The core flooding experiment shows that the depressurization rate reaches 29.62% in the 1500 mg/L SCF dispersion. Therefore, SCFs have broad application prospects in processes that eliminate water lock, reduce injection pressure, and increase injection volume.

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Advances in enhanced oil recovery technologies for low permeability reservoirs

Cited by 103 publications

References 199 publications

Pilot Test for Nitrogen Foam Flooding in Low Permeability Reservoir

Pilot Test for Nitrogen Foam Flooding in Low Permeability Reservoir

Dynamic Features of Nonaqueous Foam in Fracture Systems

Preparation of SiO₂-Fluorinated Acrylate Polymer Nanoemulsions (SCFs) and Their Application as Depressurization and Injection Treatment Agents

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Advances in enhanced oil recovery technologies for low permeability reservoirs

Cited by 103 publications

References 199 publications

Pilot Test for Nitrogen Foam Flooding in Low Permeability Reservoir

Pilot Test for Nitrogen Foam Flooding in Low Permeability Reservoir

Dynamic Features of Nonaqueous Foam in Fracture Systems

Preparation of SiO2-Fluorinated Acrylate Polymer Nanoemulsions (SCFs) and Their Application as Depressurization and Injection Treatment Agents

Contact Info

Product

Resources

About

Preparation of SiO₂-Fluorinated Acrylate Polymer Nanoemulsions (SCFs) and Their Application as Depressurization and Injection Treatment Agents