Skip to Main Content
Skip Nav Destination

Permeability measurements made using innovative techniques on 36 intact samples from five wells in south Texas provide the basis for a dual-porosity reservoir simulation model for the Eagle Ford Shale (Upper Cretaceous). In the model, matrix storage feeds a network of progressively larger natural and induced fractures that carry hydrocarbons to the wellbore. The Eagle Ford consists almost entirely of interbedded marl and limestone. Across these rock types, permeability increases with increasing calcite content. The limestones are more permeable than the marls due to the presence of fractures. Permeability also increases with the degree of lamination but the mechanism...

You do not currently have access to this chapter.

Figures & Tables

Contents

References

Related

Citing Books via

Related Book Content
Close Modal

or Create an Account

Close Modal
Close Modal