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Research Papers: Petroleum Engineering

Effect of Slick Water on Permeability of Shale Gas Reservoirs

[+] Author and Article Information
Bin Yuan

State Key Laboratory of Oil and Gas Reservoir
Geology and Exploitation,
Southwest Petroleum University,
Chengdu 610500, China
e-mail: yuanbin19880118@126.com

Yongqing Wang

State Key Laboratory of Oil and Gas Reservoir
Geology and Exploitation,
Southwest Petroleum University,
Chengdu 610500, China
e-mails: swpiwyq@163.com; xnsy2008@163.com

Zeng Shunpeng

School of Petroleum and
Natural Gas Engineering,
Chongqing University of Science and
Technology,
Chongqing 401331, China

1Corresponding authors.

Contributed by the Petroleum Division of ASME for publication in the JOURNAL OF ENERGY RESOURCES TECHNOLOGY. Manuscript received August 29, 2016; final manuscript received May 14, 2018; published online June 12, 2018. Assoc. Editor: Ray (Zhenhua) Rui.

J. Energy Resour. Technol 140(11), 112901 (Jun 12, 2018) (7 pages) Paper No: JERT-16-1350; doi: 10.1115/1.4040378 History: Received August 29, 2016; Revised May 14, 2018

In this study, we analyzed the flow-back resistance of slick water fracturing fluid in shale reservoirs. The flow-back resistance mainly includes capillary force, Van der Waals (VDW) force, hydrogen bond force, and hydration stress. Shale of Lower Silurian Longmaxi Formation (LSLF) was used to study its wettability, hydration stress, and permeability change with time of slick water treatment. The results reveal that wettability of LSLF shale was more oil-wet before immersion, while it becomes more water-wet after immersion. The hydration stress of the shale increased with increasing immersion time. The permeability decreased first, then recovered with increasing immersion time. The major reason for permeability recovery is that the capillary effect (wettability) and the shale hydration make macrocracks extension and expansion and hydration-induced fractures formation.

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Figures

Grahic Jump Location
Fig. 1

The schematic diagram of experimental principle

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Fig. 2

Flow chart of experimental procedure

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Fig. 3

Drops of paraffin oil and distilled water placed on original shale samples: (a) LSLF1, (b) LSLF2, and (c) LSLF3. Drops of paraffin oil and distilled water placed on immersed shale samples (immersed 15 h): (d) LSLF1, (e) LSLF2, and (f) LSLF3.

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Fig. 4

The relationship between hydration stress and immersion time

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Fig. 5

CT scanning image of sample before and after hydration. (a) Before hydration, (b) hydration 80 h, and (c) hydration 160 h.

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Fig. 6

Permeability of shale samples change with immersion time

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Fig. 7

Permeability of shale samples change with immersion time (immersed 70 h)

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Fig. 8

Schematic of the force model of microcrack surface

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Fig. 9

The relationship between stress intensity factor and immersion time

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