Production EngineeringWell Performance
Wellbore Storage Due to Fluid Level Formula
Wellbore Storage Due to Fluid Level calculates wellbore storage coefficient due to fluid level for well performance workflows in production engineering.
How engineers use this formula
Use this formula when the listed inputs (A_a, rho) are known and the assumptions behind the cited well performance 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_FL equals 0.020549 bbl/psi.
A_aft2
0.05
rholb/ft3
62.4
Inputs
A_a
ft2Annulus Cross-Sectional Area
rho
lb/ft3Wellbore Fluid Density
Outputs
C_FL
bbl/psi
Wellbore Storage Coefficient Due to Fluid Level
A_a
ft2
Annulus Cross-Sectional Area
rho
lb/ft3
Wellbore Fluid Density
Source and review
reviewedAdvanced Reservoir Engineering, Ahmed, T., McKinney, P.D. (2005)
Ahmed, T. and McKinney, P.D. 2005. Advanced Reservoir Engineering, Gulf Publishing of Elsevier, Chapter 1, Page 49.
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