International Journal of Oil, Gas and Coal Engineering
Volume 7, Issue 1, January 2019, Pages: 13-20
Received: Aug. 8, 2018;
Accepted: Sep. 20, 2018;
Published: Jan. 24, 2019
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Zhongbao Wu, Research Institute of Petroleum Exploration & Development, Petro China, Beijing, China
Hydraulic fracturing has become an indispensable stimulation measure for low permeability reservoirs, but how to quantitatively establish the fracturing geological model of this kind of reservoir has been an important factor restricting the progress of numerical research on overall hydraulic fracturing reservoirs. Based on the basic hypothesis of hydraulic fracturing and considering the heterogeneity of fracturing parameters, the mathematical models of fracture conductivity, permeability and porosity are deduced by reservoir engineering method, and the corresponding software is compiled to calculate quantitatively the geological parameters at any point of a single artificial fracture and its geological model is established. This model is applied to Sai 309 well area of Suijing oilfield in Changqing. Firstly, according to the geologic and development characteristics of the oilfield, unstable well test analysis method is used to quantitatively analyze the fracture parameters of fractured wells by using the existing formation testing data of wells, and then the critical geological factors and hydraulic fracturing operation parameters are selected to establish artificial neural network. Based on the trained neural network to predict the half-length of artificial fractures and the fracture conductivity of other wells without formation testing data, the porosity and permeability geological model of the fractures in hydraulic fracturing reservoir is established by using the above mathematical model, which lay a foundation for numerical simulation of fracture- matrix coupling in this kind of reservoir.
Analytical Fracture Models for Overall Hydraulic Fracturing Reservoirs, International Journal of Oil, Gas and Coal Engineering.
Vol. 7, No. 1,
2019, pp. 13-20.
Copyright © 2019 Authors retain the copyright of this article.
This article is an open access article distributed under the Creative Commons Attribution License (http://creativecommons.org/licenses/by/4.0/
) which permits unrestricted use, distribution, and reproduction in any medium, provided the original work is properly cited.
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