Method for optimizing multi-section fractured horizontal well network crack parameter

Abstract

The invention discloses a method for optimizing the multi-section fractured horizontal well network crack parameter. The method comprises the steps that a reservoir characteristic parameter of a target block is obtained; based on the reservoir characteristic parameter, a model of network cracks, including main cracks and secondary cracks, of a multi-section fractured horizontal well of the target block is established; the network crack parameter of the network crack model is designed; and based on the orthogonal test method, the network crack parameter is optimized and determined. According to the method, the optimal network crack parameter setting of the multi-section fractured horizontal well including the main cracks and the secondary cracks can be obtained at a time, and an optimized result can effectively guide fracturing operation, greatly increase the modification volume, and remarkably improve the construction effect.

Description

technical field [0001] The invention relates to the technical field of petroleum exploitation, in particular to a method for optimizing fracture parameters of a multi-stage fracturing horizontal well network. Background technique [0002] With the large-scale development and utilization of tight oil and gas reservoirs and shale oil and gas reservoirs, volume fracturing technology has been gradually popularized and applied. Tight oil and gas reservoirs and shale oil and gas reservoirs are unconventional natural gas resources, characterized by complex reservoir lithology, poor matrix permeability, and well-developed lamellar bedding. Generally, they have no natural productivity. The network fracture system formed after fracturing is the main Seepage channel. The purpose of volume fracturing is to form a fracture network system in which the fracture height runs through the entire effective reservoir thickness vertically and multiple main fractures and branch fractures intersec...

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Problems solved by technology

Compared with the actual situation in the field, this method has many limitations: it does not consider the multi-fracture system; it simply assumes that the support fracture height from the wellbore to the end of the fracture is constant; the fracture conductivity is a constant value; Influence of commonly used modes such as proppant slug sand addition

Therefore, there is no guiding significance for simulating the production behavior of shale gas wells after fracturing using conventional methods

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