Subsea MEG Injection Rate & Hydrate Inhibition Calculator

Calculate required Monoethylene Glycol (MEG) dosage (kg/h and GPM) to prevent subsea natural gas hydrate plug formation using the Hammerschmidt equation.

Subsea Pipeline Operating Conditions

Uninhibited Hydrate Temp T_h (°C):

Minimum Seabed Ambient Temp T_seabed (°C):

Produced Free Water Rate (m³/day):

Lean MEG Feed Concentration (% wt):

Safety Temperature Margin (°C): Standard flow assurance margin: 3°C - 5°C

Inhibitor Type:

Inhibitor Dosing & Rich MEG Concentration

Lean MEG Injection Rate:

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Required Rich MEG wt%:

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Target Hydrate Depression:

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Volumetric Injection (GPM):

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Hydrate Protection Status:

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Frequently Asked Questions

What is thermodynamic gas hydrate inhibition?

Thermodynamic inhibitors like Monoethylene Glycol (MEG) or Methanol form strong hydrogen bonds with water molecules, lowering water chemical activity and shifting the hydrate equilibrium dissociation curve to significantly lower temperatures.

What is the Hammerschmidt equation?

Developed by Elmer Hammerschmidt in 1934, ΔT = (2335·W)/(M·(100 - W)) calculates the Fahrenheit depression in natural gas hydrate formation temperature as a function of inhibitor molecular weight and aqueous mass fraction.

Why is MEG preferred over methanol for deepwater subsea tied-backs?

Methanol has high vapor pressure and dissolves excessively into hydrocarbon condensate, requiring massive makeup volumes. MEG stays overwhelmingly in the water phase and can be continuously regenerated in topside MEG reclamation units (MRUs).