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Research Papers: Petroleum Engineering

Experimental Simulation on Imbibition of the Residual Fracturing Fluid in Tight Sandstone Reservoirs

[+] Author and Article Information
Xiaoxia Ren

School of Petroleum Engineering,
Research Centre of Multiphase
Flow in Porous Media,
China University of Petroleum,
No. 66, Changjiang West Road,
Huangdao,
Qingdao, Shandong 266580, China
e-mail: renxiaoxia1010@163.com

Aifen Li

School of Petroleum Engineering,
Research Centre of Multiphase
Flow in Porous Media,
China University of Petroleum,
No. 66, Changjiang West Road,
Huangdao,
Qingdao, Shandong 266580, China
e-mail: aifenli123@163.com

Asadullah Memon

School of Petroleum Engineering,
Research Centre of Multiphase
Flow in Porous Media,
China University of Petroleum,
No. 66, Changjiang West Road,
Huangdao,
Qingdao, Shandong 266580, China
e-mail: 2115301762@qq.com

Shuaishi Fu

School of Petroleum Engineering,
Research Centre of Multiphase
Flow in Porous Media,
China University of Petroleum,
No. 66, Changjiang West Road,
Huangdao,
Qingdao, Shandong 266580, China
e-mail: floatingoliver@qq.com

Guijuan Wang

School of Petroleum Engineering,
Research Centre of Multiphase
Flow in Porous Media,
China University of Petroleum,
No. 66, Changjiang West Road,
Huangdao,
Qingdao, Shandong 266580, China
e-mail: 1047956103@qq.com

Bingqing He

School of Petroleum Engineering,
Research Centre of Multiphase
Flow in Porous Media,
China University of Petroleum,
No. 66, Changjiang West Road,
Huangdao,
Qingdao, Shandong 266580, China
e-mail: 415255423@qq.com

1Corresponding author.

Contributed by the Petroleum Division of ASME for publication in the JOURNAL OF ENERGY RESOURCES TECHNOLOGY. Manuscript received August 29, 2018; final manuscript received January 24, 2019; published online February 27, 2019. Assoc. Editor: Ray (Zhenhua) Rui.

J. Energy Resour. Technol 141(8), 082906 (Feb 27, 2019) (9 pages) Paper No: JERT-18-1675; doi: 10.1115/1.4042734 History: Received August 29, 2018; Revised January 24, 2019

Fracturing is a fundamental technique for enhancing oil recovery of tight sandstone reservoir. The pores in tight reservoirs generally have small radii and generate tremendous capillary force; accordingly, the imbibition effect can significantly affect retention and absorption of the fracturing fluid. In this study, the imbibition behaviors of the fracturing fluid were experimentally investigated, and the effects of interfacial tension, (IFT) permeability, oil viscosity, and the salinity of the imbibition fluid were determined. In addition, combining with nuclear magnetic resonance (NMR)-based core analysis, fluid distribution, and the related variations in imbibition and displacement processes were analyzed. Finally, some key influencing factors of imbibition of the residual fracturing fluid, the difference and correlation between imbibition and displacement, as well as the contribution of imbibition to displacement were explored so as to provide optimization suggestions for guiding the application of oil-displacing fracturing fluid in exploration. Results show that imbibition recovery increased with time, but the imbibition rate gradually dropped. There exists an optimal interfacial tension that corresponds to maximum imbibition recovery. In addition, imbibition recovery increased as permeability and salinity increases and oil viscosity decreases. Furthermore, it was found that extracted oil from the movable pore throat space was almost equal to that from the irreducible pore throat space during imbibition and their contribution in the irreducible pore throat space was greater than in the movable pore throat space in the displacement process. Hence, imbibition plays a more important role during the displacement process in the reservoirs with finer porous structure than previously thought.

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Figures

Grahic Jump Location
Fig. 1

Illustration of fracturing fluid imbibition process

Grahic Jump Location
Fig. 2

Imbibition instrument

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Fig. 3

Images of imbibition process in A-4 core at different moments: (a) 0.5 h, (b) 2.5 h, (c) 3.5 h, (d) 4.5 h, and (e) 7 days

Grahic Jump Location
Fig. 4

Variations of imbibition quantity with time under different interfacial tensions: (a) Kg ≈ 0.2×10−3 μm2, (b) Kg ≈ 0.7×10−3 μm2, and (c) Kg ≈ 1.2×10−3 μm2

Grahic Jump Location
Fig. 5

Variation of imbibition recovery with interfacial tension

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Fig. 6

Imbibition volumes with different permeability values at different times (different interfacial tension systems): (a) 0.316 mN/m, (b) 0.869 mN/m, (c) 4.448 mN/m, and (d) 10.815 mN/m

Grahic Jump Location
Fig. 7

The relationship between imbibition recovery and core permeability in different interfacial tension systems

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Fig. 8

Effect of oil viscosity imbibition performance: (a) variations of imbibition quantity with time with various oil viscosities and (b) relationship between imbibition recovery and oil viscosity

Grahic Jump Location
Fig. 9

Effect of salinity on imbibition performance: (a) variations of imbibition quantity with time for imbibition liquids with different salinities and (b) relationship between imbibition recovery and the salinity of imbibition iquid

Grahic Jump Location
Fig. 10

Imbibition behaviors of M 1-2 core in TOF-1 solution with a volume fraction of 5%: (a) T2 relaxation time spectra of imbibition behaviors in the core at different times and (b) distribution of irreducible water, extracted oil and residual oil

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Fig. 11

T2 relaxation time spectra of M 1-2 core after imbibition and displacement, respectively

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Fig. 12

Recovery from different pores of M 1-2 core sample under imbibition and displacement, respectively, as well as the contribution of imbibition to displacement

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