Rock deformability can greatly affect the response of naturally fractured reservoirs when subjected to changes in fluid pressure. This paper describes two numerical models that were developed to understand some of the fluid-rock interactions that can take place in this type of reservoir. Both models were used to study the response of a small ‘sugar block’ reservoir dissected by a large number of fractures and subjected to a number of field conditions and production rates. Results obtained during this preliminary phase indicate that fracture deformability plays a fundamental role in reservoir performance, and the associated compaction can represent an additional drive mechanism, even if significant reductions in fracture permeability are expected.

The newly developed models are useful reservoir management tools which allow to investigate the effect of matrix porosity and permeability, fracture aperture, mechanical properties, anisotropy and production rates on reservoir performance.

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