Reservoir EngineeringRock Properties
Total Pore Volume Compressibility Formula
Total Pore Volume Compressibility calculates total pore volume compressibility for rock properties workflows in reservoir engineering.
How engineers use this formula
Use this formula when the listed inputs (PV_i, PV_p, P_i, P) 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, c_f equals 0.00001 1/psi.
PV_ibbl
1000000
PV_pbbl
990000
P_ipsi
4000
Ppsi
3000
Inputs
PV_i
bblPore Volume at Initial Pressure
PV_p
bblPore Volume at Pressure P
P_i
psiInitial Pressure
P
psiCurrent Pressure
Outputs
c_f
1/psi
Total Pore Volume Compressibility
PV_i
bbl
Pore Volume at Initial Pressure
PV_p
bbl
Pore Volume at Pressure P
P_i
psi
Initial Pressure
P
psi
Current Pressure
Source and review
reviewedAhmed, T., McKinney, P.D. 2005. Advanced Reservoir Engineering, Gulf Publishing of Elsevier, Chapter 3, Page 213.
Source