Geomechanics and FracturingNaturally Fractured Reservoirs

Fracture Porosity from Aperture and Volumetric Intensity Formula

\phi_f=b_fP_{32}

Fracture Porosity from Aperture and Volumetric Intensity calculates fracture porosity for naturally fractured reservoirs workflows in geomechanics and fracturing.

Calculate

How engineers use this formula

Use this formula when the listed inputs (b_f, P32) are known and the assumptions behind the cited naturally fractured reservoirs relationship match the engineering case being checked.

Assumptions

Input values are representative for the well, reservoir, fluid, or equipment case being evaluated.
The declared units match the field-unit constants used in the formula.
The cited formula applies to the selected petroleum engineering workflow.

Limitations

The calculation does not replace a full engineering model or operating procedure.
Accuracy depends on the source correlation, assumptions, input quality, and unit consistency.

Common mistakes

Mixing unit systems without converting the inputs.
Using default example values as field recommendations.
Applying the formula outside the source assumptions.

Default example

Using the default inputs, phi_f equals 0.002 fraction.

b_fft

0.01

P321/ft

0.2

Inputs

b_f

Average Fracture Aperture

P32

1/ft

Volumetric Fracture Intensity

Outputs

phi_f

fraction

Fracture Porosity

b_f

Average Fracture Aperture

P32

1/ft

Volumetric Fracture Intensity

Source and review

reviewed

Derived from the TU Bergakademie Freiberg P32 definition as fracture area per unit rock volume.

Source