Overview
In gas and offshore production systems, MEG is a proven hydrate inhibitor used to prevent solid hydrate formation under cold, high-pressure conditions. That protection is critical for maintaining reliable flow through subsea infrastructure and gas transport systems.
Beyond chemistry, MEG programs depend on dependable supply, storage, and delivery discipline. For many operators, logistics capability is just as important as product quality.
Selection note: For this dedicated page, the focus is MEG in oil and gas hydrate-inhibition service rather than general industrial coolant use.
Typical Applications
- Subsea flowlines and offshore systems with hydrate risk
- Gas production and transport networks requiring continuous inhibition
- Onshore and offshore facilities supplied through bulk or vessel-based logistics
- Operations where uninterrupted MEG availability is essential to flow assurance
Operational Considerations
- Hydrate risk depends on pressure, temperature, water content, and operating envelope.
- MEG quality, recovery strategy, and logistics planning all affect lifecycle cost.
- Field programs should be coordinated with storage, injection, and offshore supply constraints.
TEG vs. MEG Selection
| Criterion | TEG | MEG |
|---|---|---|
| Primary function | Gas dehydration (absorber) | Hydrate inhibition (injection) |
| Application method | Continuous circulation in contactor | Continuous injection & recovery |
| Regeneration temperature | ~200°C (atmospheric) | ~130°C (atmospheric) |
| Achievable dewpoint | −10°C to −25°C | Not applicable (hydrate control) |
| Vapour pressure | Very low — minimal gas-phase losses | Higher — more volatile |
| Thermal stability | Excellent up to ~200°C | Good up to ~130°C |