Method and device for predicting fluid pressure coefficient of shale formation rich in organic matters

Abstract

The invention discloses an organic-matter-rich mud shale formation fluid pressure coefficient prediction method and device, a storage medium and computer equipment, and the method comprises the steps: based on apatite fission track age and length distribution data, through fission track length simulation, determining the uplift time and the uplift denudation process, and according to ancient temperature scale Ro data, through ancient temperature scale inversion, calculating the fission track length distribution data; the method comprises the following steps: determining the uplift time, determining the denudation amount, on the basis of the uplift time, the denudation amount and denudation amount recovery, obtaining the maximum vertical effective pressure endured by the shale in the geological historical period through burial history recovery, and after the maximum vertical effective pressure and the current vertical effective pressure are determined, determining the OCR value of the shale. According to the method, the formation fluid pressure coefficient of the shale rich in organic matters is predicted by utilizing the OCR value according to the mathematical model, so that a key parameter index is provided for geological evaluation and engineering evaluation of exploration.

Description

Technical field [0001] The present invention relates to the field of ocean and land geophysical exploration technologies, and in particular, to seismic data treatment in seismic sludge formation fluid pressure coefficient prediction methods, devices, and corresponding storage media and computer equipment. Background technique [0002] The formation fluid pressure (or formation pressure, pore pressure, fluid pressure, etc.) coefficient is the ratio of the formation pressure at a depth of the ground and the hydrostatic pressure at the depth. According to the size of the stratum pressure coefficient, the stress characteristics of the formation can be divided into overpressure, normal pressure, and low pressure. Due to the action of cheese root hydrocarbons or liquid hydrocarbon cleaves, overpressure is the geological phenomenon in richest mud shale, or at least overpressure in the geological historical period, even for normal pressure. [0003] China's southern phase landscape is wi...

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Problems solved by technology

Generally, overpressure shale gas reservoirs have high free gas content and high single well production, while normal pressure shale gas reservoirs have relatively high adsorbed gas content and low single well production.

The fluid pressure of the Longmaxi Formation in the shale gas exploration wells outside the Sichuan Basin is now normal pressure, reflecting that the preservation conditions have been damaged to a certain extent

[0006] Exploration practice has proved that the above-mentioned existing formation fluid pressure coefficient prediction methods have limitations, especially for marine highly evolved shale in southern China, for example, there is still a huge challenge in accurately predicting the pressure coefficient

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