Production EngineeringWell Performance
Workover Operations Maximum Allowed Tubing Pressure Formula
Workover Operations Maximum Allowed Tubing Pressure calculates maximum allowed tubing pressure for well performance workflows in production engineering.
How engineers use this formula
Use this formula when the listed inputs (FG, H, P_t) 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, MATP equals 2,500 psi.
FGpsi/ft
0.75
Hft
8000
P_tpsi
3500
Inputs
FG
psi/ftFracture Gradient
H
ftDepth of Perforations
P_t
psiTubing Pressure
Outputs
MATP
psi
Maximum Allowed Tubing Pressure
FG
psi/ft
Fracture Gradient
H
ft
Depth of Perforations
P_t
psi
Tubing Pressure
Source and review
reviewedPetroWiki workover operations pressure-limit relation, as mirrored by PetroleumEngineers.Net.
SourceRelated formulas and calculators
Effective Wellbore Radius of a Well in Presence of Uniform Flux Fractures
Well Performance
Effective Wellbore Radius of a Horizontal Well – Method 1 (Anisotropic Reservoirs)
Well Performance
Effective Wellbore Radius of a Horizontal Well – van der Vlis et al. Method
Well Performance