Fracture-cavern type carbonate condensate gas well development index analyzing method and device

Abstract

The invention provides a fracture-cavern type carbonate condensate gas well development index analyzing method and device. The method includes the steps of obtaining a standard parameter in a single well, calculating the dynamic reserve volume of the single well according to the standard parameter, determining the natural gas yield and natural gas accumulated yield of all production time points according to the preset natural gas yield segmented decreasing rule, determining the two-phase deviation coefficient and gas-oil ratio data according to PVT experimental data, establishing a matter balance equation, substituting the natural gas accumulated yield and the two-phase deviation coefficient into the equation, calculating stratum pressure theoretical values of all the production time points, conducting correction to generate a stratum pressure correction value according to actually-measured static pressure data, predicting the corresponding condensate oil yield according to the stratum pressure correction value and the gas-oil ratio data, calculating the condensate oil accumulated yield according to the matter balance equation with abandoned stratum pressure as a restraint, and calculating the condensate oil production degree and the natural gas production degree through the combination of the dynamic reserve volume of the single well.

Description

technical field [0001] The invention belongs to the technical field of condensate gas reservoir development, and in particular relates to a method and device for analyzing development indexes of fractured-cavity carbonate rock condensate gas wells. Background technique [0002] For the development of fractured-cavity carbonate condensate gas reservoirs, it has three typical characteristics: 1) The reservoir properties are complex, with different degrees of pores, caves, fractures and other storage media developed, and the reservoirs have extremely strong Heterogeneity; 2) The fluid properties are complex, and the state of oil and gas changes with the reservoir pressure; 3) The production law is complex, the production of condensate oil, natural gas production, and formation pressure decrease rapidly, and it cannot be determined according to the bottom hole flow pressure. Or the way of fixed production at the wellhead for production. Generally speaking, this type of condensa...

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Problems solved by technology

[0002] For the development of fractured-cavity carbonate condensate gas reservoirs, it has three typical characteristics: 1) The reservoir properties are complex, with different degrees of pores, caves, fractures and other storage media developed, and the reservoirs have extremely strong Heterogeneity; 2) The fluid properties are complex, and the state of oil and gas changes with the reservoir pressure; 3) The production law is complex, the production of condensate oil, natural gas production, and formation pressure decrease rapidly, and it cannot be determined according to the bottom hole flow pressure. Or wellhead fixed production method for production

Generally speaking, this type of condensate gas reservoir has strong heterogeneity, poor connectivity between wells, and limited control range of a single well. Fluid phase changes, each seepage storage unit has different production characteristics

[0003] There are relatively few studies on the development of fractured-cavity carbonate condensate gas reservoirs at home and abroad. Conventional analysis methods are not applicable to this type of gas reservoirs, and have great limitations, and the accuracy of prediction results is low.

For example, if the numerical simulation method is used to predict the development index of fracture-cavity condensate gas wells, in addition to the difficulty of geological modeling and the difficulty of providing a relatively reliable geological model, conventional seepage mathematical models are used to describe large-scale media such as large vugs, large pores, and large fractures There are still big differences in the applicability of the flow law of the internal fluid

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