Lithologic Reservoirs ›› 2016, Vol. 28 ›› Issue (3): 48-57.doi: 10.3969/j.issn.1673-8926.2016.03.008

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Quantitative characterization of pore structure in shale reservoir of Longmaxi Formation in Sichuan Basin

GongXiaoping 1，2， TangHongming 1，2， ZhaoFeng 1，2， WangJunjie 1，2， XiongHao 1，2   

  1. 1. State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation ， Southwest Petroleum University ， Chengdu 610500 ， China ； 2. School of Geoscience and Technology ， Southwest Petroleum University ， Chengdu 610500 ， China
  • Online:2016-05-20 Published:2016-05-20

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Abstract:

Quantitative characterization of pore structure in shale can indicate some basic parameters for shale reservoir quality evaluation. However, it is difficult to use conventional methods to accurately characterize the micron to nano-scale pore structure in shale. This paper took gas-bearing shale of Longmaxi Formation in Sichuan Basin as a study object to comprehensively compare the principles, advantages and disadvantages of the mostly used test approaches such as nitrogen adsorption, high-pressure mercury injection and nuclear magnetic resonance（NMR）, etc. Nitrogen adsorption method is usually used to test the pore which is 1-50 nm in size, high-pressure mercury injection method is proposed to test for macropore （> 50 nm）, and NMR can reflect the pore size distribution by testing the relaxation time （T2） spectrum of the saturated fluid in shale. The pore size in shale is positively related to the T2 value tested by NMR and there exists a conversion coefficient （C）. A new method of combining NMR with low-pressure nitrogen adsorption for testing pore size distribution in shale was proposed, which optimizes the conversion coefficient （C） between pore size （D） tested by low-pressure nitrogen adsorption method and T2 value tested by NMR method firstly, and then the pore size distribution can be characterized by NMR based on the C value. Large amounts of micron-fractures could be caused in the process of high-pressure mercury injection, and these fractures are considered to be artificial fractures which is difficult to distinguish from natural micro-fractures, so the new method can make up for the deficiency of the conventional method for pore size distribution characterization by combining lowpressure nitrogen adsorption and high-pressure mercury injection. In addition, because of the advantages of simple sample processing, small artificial destruction, no external pressure, etc, it is recommended to characterize the pore structure by combining low-pressure nitrogen adsorption and NMR to reflect the pore throat distribution scientifically and accurately. The result shows that the pore size distribution in Longmaxi shale is bimodal or trimodal, and the main pore size is 0.2-100.0 nm. The mesopore and micropore are predominated, and their volume percents are 67.75% and 25.33% respectively. This method was used to quantitatively characterize the pore structure in shale in the study area, and the test result accords with the pore structure characteristics of Longmaxi shale.

Key words: shale , pore structure , low-pressure nitrogen adsorption , high-pressure mercury injection , nuclear magnetic resonance , quantitative characterization , Longmaxi Formation , Sichuan Basin

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