Reservoir EngineeringReservoir Volumetrics
Pore Volume from Net Rock Volume and Porosity Formula
Pore Volume from Net Rock Volume and Porosity calculates reservoir pore volume for reservoir volumetrics workflows in reservoir engineering.
How engineers use this formula
Use this formula when the listed inputs (V_nrv_bbl, phi) are known and the assumptions behind the cited reservoir volumetrics 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, PV equals 10,054,368 bbl.
V_nrv_bblbbl
55857600
phifraction
0.18
Inputs
V_nrv_bbl
bblNet Rock Volume
phi
fractionAverage Reservoir Porosity
Outputs
PV
bbl
Reservoir Pore Volume
V_nrv_bbl
bbl
Net Rock Volume
phi
fraction
Average Reservoir Porosity
Source and review
reviewedPenn State PNG 301. Volumetric method phase-volume terms include average reservoir porosity.
Source