Shale Formation Damage during Fracturing Fluid Imbibition and Flowback Process Considering Adsorbed Methane

Mingjun Chen (), Maoling Yan, Yili Kang, Sidong Fang, Hua Liu, Weihong Wang, Jikun Shen and Zhiqiang Chen
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Mingjun Chen: State Key Laboratory of Shale Oil and Gas Enrichment Mechanisms and Effective Development, Beijing 100083, China
Maoling Yan: Petroleum Engineering School, Southwest Petroleum University, Chengdu 610500, China
Yili Kang: Petroleum Engineering School, Southwest Petroleum University, Chengdu 610500, China
Sidong Fang: State Key Laboratory of Shale Oil and Gas Enrichment Mechanisms and Effective Development, Beijing 100083, China
Hua Liu: State Key Laboratory of Shale Oil and Gas Enrichment Mechanisms and Effective Development, Beijing 100083, China
Weihong Wang: State Key Laboratory of Shale Oil and Gas Enrichment Mechanisms and Effective Development, Beijing 100083, China
Jikun Shen: Petroleum Engineering School, Southwest Petroleum University, Chengdu 610500, China
Zhiqiang Chen: Petroleum Engineering School, Southwest Petroleum University, Chengdu 610500, China

Energies, 2022, vol. 15, issue 23, 1-14

Abstract: Hydraulic fracturing of shale gas reservoirs is characterized by large fracturing fluid consumption, long working cycle and low flowback efficiency. Huge amounts of fracturing fluid retained in shale reservoirs for a long time would definitely cause formation damage and reduce the gas production efficiency. In this work, a pressure decay method was conducted in order to measure the amount of fracturing fluid imbibition and sample permeability under the conditions of formation temperature, pressure and adsorbed methane in real time. Experimental results show that (1) the mass of imbibed fracturing fluid per unit mass of shale sample is 0.00021–0.00439 g/g considering the in-situ pressure, temperature and adsorbed methane. (2) The imbibition and flowback behavior of fracturing fluid are affected by the imbibition or flowback pressure difference, pore structure, pore surface properties, mechanical properties of shale and mineral contents. (3) 0.01 mD and 0.001 mD are the critical initial permeability of shales, which could be used to determine the relationship between the formation damage degree and the flowback pressure difference. This work is beneficial for a real experimental evaluation of shale formation damage induced by fracturing fluid.

Keywords: shale gas; fracturing fluids; imbibition; flowback; formation damage; pore structure (search for similar items in EconPapers)
JEL-codes: Q Q0 Q4 Q40 Q41 Q42 Q43 Q47 Q48 Q49 (search for similar items in EconPapers)
Date: 2022
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