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. 2023 Apr 18;8(17):15553-15563.
doi: 10.1021/acsomega.3c00882. eCollection 2023 May 2.

Laboratory Experiment and Application Evaluation of a Bio-Nano-depressurization and Injection-Increasing Composite System in Medium-Low Permeability Offshore Reservoirs

Qing Feng  1 , Xianchao Chen  2 , Ning Zhang  3 , Xiaonan Li  1 , Jingchao Zhou  2 , Shengsheng Li  1 , Xiaorong Zhang  4 , Yanni Sun  4 , Yuehui She  5   6
Affiliations

Laboratory Experiment and Application Evaluation of a Bio-Nano-depressurization and Injection-Increasing Composite System in Medium-Low Permeability Offshore Reservoirs

Qing Feng et al. ACS Omega. .

Abstract

Given the high injection pressure and insufficient injection volume in the offshore oilfield, Bohai Oilfield has developed a bio-nano-depressurization and injection-increasing composite system solution (bio-nano-injection-increasing solution) composed of bio-surfactants, hydrophobic nano-polysilicon particles, and dispersant additives. In response to the current problems, a new type of bio-nano-depressurization and injection enhancement technology has been studied, which has multiple functions such as nano-scale inhibition and wetting reversal. The new technology has the technical advantages of efficient decompression, long-term injection, and wide adaptation. However, there is still a lack of optimization schemes and application effect prediction methods, which hinder the further popularization and application of the bio-nano-composite system solution. To solve this problem, this paper takes Well A1 in the Bohai Sea as an example to optimize the injection volume, concentration, and speed of the bio-nano-augmentation fluid and evaluates the application effect by using the proposed well testing, water absorption index, and numerical simulation methods. The research results show that the bio-nano-injection fluid can effectively improve the reservoir permeability and reduce the injection pressure. The application effect evaluation method proposed is reliable and can provide some reference for similar depressurization and injection-increasing technologies.

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Conflict of interest statement

The authors declare no competing financial interest.

Figures

Figure 1
Figure 1
Pictures of experimental instrument [(a) constant flow pump; (b) ultrapure water manufacturing system; (c) electron microscope; (d) optical contact angle meter; and (e) ultrasonic stirrer].
Figure 2
Figure 2
Schematic diagram of conceptual model.
Figure 3
Figure 3
Relative permeability curve.
Figure 4
Figure 4
Schematic diagram of the influence of nano-particles on reservoir stratum.
Figure 5
Figure 5
Schematic diagram of the geological model.
Figure 6
Figure 6
Influence of injected PV number on core permeability. (a) Effect of nano-solution on the wetting angle of the low-permeability core. (b) Effect of nano-solution on the wetting angle of the medium-permeability core.
Figure 7
Figure 7
SEM image of rock slice [(a,b) blank, (c,d) adsorbed bio-nano].
Figure 8
Figure 8
Results of the determination of the corrosion rate.
Figure 9
Figure 9
SEM images of minerals (montmorillonite) before and after dissolution.
Figure 10
Figure 10
SEM images before and after dissolution of cuttings.
Figure 11
Figure 11
Influence of injection volume on permeability.
Figure 12
Figure 12
Influence of injection rate on permeability.
Figure 13
Figure 13
Influence of injection volume on application consequent.
Figure 14
Figure 14
Influence of injection concentration on application consequent.
Figure 15
Figure 15
Influence of injection rate on application consequent.
Figure 16
Figure 16
Fitting diagram of well testing.
Figure 17
Figure 17
Fitting diagram of apparent water injectivity index.
See this image and copyright information in PMC

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