An Optimal Inversion Method for Mineral Composition Models of Shale Oil and Gas Reservoirs

Abstract

The present invention provides a shale oil and gas reservoir mineral composition model optimization inversion method, comprising the following steps: S1 constructing a shale oil and gas reservoir mineral composition petrophysical volume model; S2 calculating the organic framework kerogen volume content; S3 calculating Inorganic framework shale content; S4 correction of three-pore curve of shale oil and gas reservoir; S5 optimal inversion of inorganic framework model based on petrophysical experiment constraints. The invention can calculate the content of each mineral component more accurately, achieve the continuous identification of the whole well section, and solve the problems of high cost of core testing, limited sampling and inability to identify the whole well section due to discontinuous samples.

Description

technical field [0001] The invention relates to the field of oil and gas exploration, in particular to an optimal inversion method for mineral component models of shale oil and gas reservoirs. Background technique [0002] The basis of shale gas reservoir evaluation is the accurate identification of shale mineral components and lithology. The mineral composition of shale plays an important role in controlling whether the shale gas reservoir has the ability to generate hydrocarbons and the reservoir can be fractured and stimulated. However, the mineral components of shale oil and gas reservoirs are diverse and the lithology is complex and changeable. How to effectively identify the mineral components of shale oil and gas reservoirs is one of the difficulties in the exploration and development of shale oil and gas. At present, there is still no effective method for identifying the mineral components of shale reservoirs. [0003] At present, there are usually several methods ...

AI Technical Summary

Problems solved by technology

However, the disadvantages of this method are: first, the cost is too high, and it is impossible to do coring and experimental testing of the entire well section downhole, so it is impossible to continuously identify the lithology of the entire well section

The second is that the core is easy to weather and deteriorate after being taken out, and it is difficult to truly reflect the mineral composition measured under the high temperature and high pressure environment underground.

The disadvantage is that this method still relies on the laboratory core to test the mineral content to construct the model. The accuracy and applicability of the model depend on the amount of core experimental data in the region, and it is difficult to promote it across regions.

The disadvantages are: First, this method belongs to special well logging, which is relatively expensive. It is only measured in important exploration wells and evaluation wells in the block. It is difficult to popularize in the whole area, and the universality is not strong.

Second, the model is mainly aimed at complex lithology such as carbonate rocks, and does not consider the impact of organic carbon content in shale oil and gas reservoirs on the logging response. The model is insufficient and the identification accuracy is lacking

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