Experimental study on microscopic mechanisms and displacement efficiency of N2 flooding in deep-buried clastic reservoirs

Su, Yuliang; Zhang, Xue; Li, Lei; Hao, Yongmao; Zhan, Shiyuan; Wu, Zangyuan; Zhang, Wenjing

doi:10.1016/j.petrol.2021.109789

Cited by 21 publications

(5 citation statements)

References 31 publications

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“…(Figure 2c); (4) When the rock surface is hydrophilic, the injected water tends to flow along the contours of the rock surface, thereby creating isolated droplets of residual oil in the central region of the larger channel. (Figure 2d); (5) In the place where a large number of small pores exists or the large pores are nearly enclosed by small pores, it becomes challenging for the injected water to create a local breakthrough and subsequently disperse the flake oil, thus forming a contiguous block of residual oil (Figure 2e) [31][32][33][34]. The distribution of various types of remaining oil after water flooding is statistically analyzed.…”

Section: Remaining Oil Distributionmentioning

confidence: 99%

Micro and Macro Flooding Mechanism and Law of a Gel Particle System in Strong Heterogeneous Reservoirs

Ye,

Wang,

et al. 2024

Gels

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To address the issue of ineffective injection resulting from the consistent channeling of injected water through highly permeable channels in ultra-deep, high-temperature, high-salinity, and strongly heterogeneous reservoirs during the production process, a gel particle profile control agent suitable for high-temperature and high-salinity conditions was chosen. With the help of the glass etching visual microscopic model and the heterogeneous long core model, the formation mechanism of a water flooding channeling path and the distribution law of the remaining oil were explored, the microscopic profile control mechanism of the different parameters was clarified, and the profile control effect of macroscopic core displacement was analyzed. The research shows that the formation mechanism of a water flooding channeling path is dominated by the distribution law of the permeability section and the connection mode between different penetration zones. The remaining oil types after water flooding are mainly contiguous block, parallel throats, and multi-branch clusters. The profile control effect of gel particles on reservoir vertical heterogeneity is better than that of reservoir lateral heterogeneity. It was found that 10 wt% submicron particles with a median diameter of 600 nm play a good role in profiling and plugging pores of 5–20 μm. In addition, 10 wt% micron-sized particles with a median diameter of 2.63 μm mainly play a strong plugging role in the pores of 20–30 μm, and 5 wt% micron-sized particles with a median diameter of 2.63 μm mainly form a weak plugging effect on the pores of 10–20 μm. The overall profile control effect of 10 wt% submicro particles is the best, and changes in concentration parameters have a more significant effect on the profile control effect. In the macroscopic core profile control, enhanced oil recovery (EOR) can reach 16%, and the gel particles show plugging, deformation migration, and re-plugging. The research results provide theoretical guidance for tapping the potential of the remaining oil in strong heterogeneous reservoirs. To date, the gel particles have been applied in the Tahe oilfield and have produced an obvious profile control effect; the oil production has risen to the highest value of 26.4 t/d, and the comprehensive water content has fallen to the lowest percentage of 32.1%.

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Section: Remaining Oil Distributionmentioning

confidence: 99%

Micro and Macro Flooding Mechanism and Law of a Gel Particle System in Strong Heterogeneous Reservoirs

Ye,

Wang,

et al. 2024

Gels

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“…Those gases maintain pressure, displace, and reduce the viscosity of oil to increase production. [136] The investigations using the microfluidics approach involved the solubility of CO 2 in MEA, [91] multiple tests in HPHT conditions such as N 2 injection [149,150] CO 2 -water alternated gas injection (WAG), [151][152][153] foam-assisted CO 2 EOR, [81,154,155] and CO 2 injection-induced formation damage. [156] Given that the injected gas has a low viscosity, a poor microscopic sweep efficiency produces fluid front instability and early breakthrough.…”

Section: Enhanced Oil Recoverymentioning

confidence: 99%

Microfluidic devices, materials, and recent progress for petroleum applications: A review

Betancur,

Quevedo,

Olmos

2024

Can J Chem Eng

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Microfluidic devices are miniaturized systems that manipulate fluids on a small scale, typically at microlitre or nanolitre volumes. They have received significant attention in various industries, including petroleum applications. The recent advancements in microfluidic devices for petroleum applications have the potential to improve oil recovery efficiency, reduce costs, and provide valuable insights into fluid behaviour and reservoir characterization. This paper aims to provide a comprehensive overview of microfluidic devices, their materials, and their applications in the petroleum industry. The first section of the paper focuses on describing the materials used in microfluidic devices specifically tailored for energy sector applications. In the second section, the paper highlights relevant applications and discoveries in petroleum research, showcasing the innovative techniques and special features enabled by microfluidic devices. These applications include but are not limited to asphaltenes characterization, enhanced oil recovery (EOR), and water treatment. The versatility and customization of microfluidic devices have allowed researchers to accurately represent fractures, ensure chemical conformance, simulate high pressure–high temperature conditions and reservoir heterogeneity, and study geochemical interaction. Additionally, molecular tagging and machine learning techniques have been employed for image analysis, further enhancing the capabilities of microfluidic devices. Throughout the paper, the advantages and disadvantages of implementing microfluidic devices and utilizing specific materials are thoroughly discussed. This analysis provides valuable insights into the challenges and potential limitations associated with this technology. To conclude, the paper offers suggestions, ideas, and highlights for future research paths, pointing toward promising directions for further exploration in this field.

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“…These processes result in a reduction in viscosity and an enhancement in flow characteristics. Gas injection can be exemplified by various scenarios, including the miscibility of CO2, immiscibility of CO2, miscibility of N2, miscibility of rich gas, miscibility of dry gas, and miscibility of LPG [14][15]. CO2 flooding is considered to be a highly promising approach for enhancing the recovery of both light and heavy oil.…”

Section: Introductionmentioning

confidence: 99%

Enhanced Oil Recovery through Carbon Dioxide Injection: A Compositional Simulation Approach

Tamanna Zafrin Orin,

Md Tauhidur Rahman,

Mohammad Amirul Islam

et al. 2024

ARASET

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Primary recovery techniques of hydrocarbons are insufficient to meet the ever-growing energy demand. This fact encourages researchers to establish tertiary hydrocarbon extraction techniques to increase production and meet the energy demand. The implementation of CO2 flooding has been widely regarded as a highly favourable approach for enhancing the recovery of both light and heavy oil resources. The rate of CO2 injection must be consistent so that viscosity decreases, and medium crude oil mobility is increased in accordance with production requirements. In this research, the compositional simulation model for CO2 flooding has been developed using Eclipse 2010.1 software with Lorentz-Bray-Clark correlation for enhanced oil recovery by reducing viscosity with constant CO2 injection. The compositional reservoir simulated model was executed from January 1, 2027 to January 1, 2050. From January 1, 2027 to January 1, 2048, the oil production rate remained constant. The concentration of CO2 in the oil phase has exhibited a notable increase, rising from 27.25% to 58.658% over the course of the twenty-three-year simulation period. This observation indicates that the oil phase has experienced a greater dissolution of CO2. Consequently, there has been a reduction in the viscosity of the reservoir oil, with a decrease from 0.126 centipoise (cp) to 0.088 cp, representing a 69.84 percent decline. Additionally, there has been an increase in the mobility of the reservoir oil. Furthermore, the enhanced oil recovery technique successfully achieved the recovery of 35.77 million stock tank barrels per day of medium crude oil. Finally, CO2 flooding reduces the amount of CO2 in nature, which is extremely significant from an environmental standpoint.

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Experimental study on microscopic mechanisms and displacement efficiency of N2 flooding in deep-buried clastic reservoirs

Cited by 21 publications

References 31 publications

Micro and Macro Flooding Mechanism and Law of a Gel Particle System in Strong Heterogeneous Reservoirs

Micro and Macro Flooding Mechanism and Law of a Gel Particle System in Strong Heterogeneous Reservoirs

Microfluidic devices, materials, and recent progress for petroleum applications: A review

Enhanced Oil Recovery through Carbon Dioxide Injection: A Compositional Simulation Approach

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