Gas Well Critical Velocity (Turner Liquid Loading) Calculator
Determine the minimum critical gas velocity (vc) and gas production rate required to lift liquid droplets and prevent wellbore liquid loading per Turner & Coleman.
Wellhead Conditions & Fluids
Critical Unloading Limits
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Frequently Asked Questions
What is liquid loading in a natural gas well?
As a gas reservoir depletes, flow velocity inside the production tubing drops. When gas velocity falls below the terminal settling velocity of liquid droplets, liquid can no longer be swept upward, accumulating in the wellbore and choking off production.
What is Turner’s critical velocity equation?
Formulated by R.G. Turner in 1969 based on droplet Weber number breakup (We=30), vc = C·[(σ·(ρL - ρg))/ρg²]^0.25 determines the minimum upward gas velocity required to suspend and transport the largest stable liquid droplet.
Why is critical gas velocity lower for condensate than formation water?
Hydrocarbon condensate has a much lower surface tension (~20 mN/m vs ~60 mN/m) and lower density (~750 vs ~1050 kg/m³). Liquid droplets break up into smaller sizes with lower terminal settling velocities, requiring less gas velocity to lift.