Tubing Bottomhole Pressure from Wellhead Pressure and Losses Formula
Tubing Bottomhole Pressure from Wellhead Pressure and Losses calculates flowing bottomhole pressure for well performance workflows in production engineering.
How engineers use this formula
Use this formula when the listed inputs (P_wh, DeltaP_h, DeltaP_f, DeltaP_acc) 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, P_wf equals 2,275 psi.
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Inputs
P_wh
psiTubing Head or Wellhead Flowing Pressure
DeltaP_h
psiHydrostatic Pressure Drop
DeltaP_f
psiFriction Pressure Drop
DeltaP_acc
psiAcceleration Pressure Drop
Outputs
P_wf
Flowing Bottomhole Pressure
DeltaP_total
Total Tubing Pressure Drop
P_wh
Tubing Head or Wellhead Flowing Pressure
DeltaP_h
Hydrostatic Pressure Drop
DeltaP_f
Friction Pressure Drop
DeltaP_acc
Acceleration Pressure Drop
Source and review
reviewedWhitson well pressure calculations and Penn State PNG 301 tubing performance discussion.
Source