PetrophysicsRock Properties
Total Porosity from Pore Volumes Formula
Total Porosity from Pore Volumes calculates total porosity for rock properties workflows in petrophysics.
How engineers use this formula
Use this formula when the listed inputs (V_i, V_d, V_b) are known and the assumptions behind the cited rock properties 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 equals 0.2 fraction.
V_icm³
18
V_dcm³
2
V_bcm³
100
Inputs
V_i
cm³Volume of Interconnected Pores
V_d
cm³Volume of Dead-End Pores
V_b
cm³Total Bulk Volume
Outputs
phi
fraction
Total Porosity
V_i
cm³
Volume of Interconnected Pores
V_d
cm³
Volume of Dead-End Pores
V_b
cm³
Total Bulk Volume
Source and review
reviewedDandekar, A.Y. 2006. Petroleum Reservoir Rock and Fluid Properties, Chapter 3, Page 15.
source conflict
Source