Phase Behavior and ThermodynamicsFluid Properties
Beggs-Robinson Live Oil Viscosity Correlation Formula
Beggs-Robinson Live Oil Viscosity Correlation calculates live oil viscosity for fluid properties workflows in phase behavior and thermodynamics.
How engineers use this formula
Use this formula when the listed inputs (mu_od, R_s) are known and the assumptions behind the cited fluid 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, mu_o equals 0.54894 cP.
mu_odcP
2
R_sSCF/STB
600
Inputs
mu_od
cPDead Oil Viscosity
R_s
SCF/STBSolution Gas-Oil Ratio
Outputs
mu_o
cP
Live Oil Viscosity
A_br_live_oil
dimensionless
Beggs-Robinson Live Oil Coefficient A
B_br_live_oil
dimensionless
Beggs-Robinson Live Oil Coefficient B
mu_od
cP
Dead Oil Viscosity
Source and review
reviewedCraft, B.C., Hawkins, M. and Terry, R.E. 1991. Applied Petroleum Reservoir Engineering, 2nd Edition, Page 41.
Source