For several decades mono-ethylene glycol (MEG) has been the primary chemical to inhibit the formation of hydrates in natural gas production pipelines and related facilities. New correlations are presented here to predict the required MEG weight percent in the rich solution and the flow rate for desired depression of the gas hydrate formation temperature. These correlations are generated for a natural gas with relative density of 0.6 at pressures of 3, 5, 7, and 9 MPa, which are applicable to wet gas temperature of 20, 30, 40, and 50°C. In order to extend the applications of these correlations to wider ranges of natural gas mixtures with specific gravities of up to 0.8, two generalized correction factors are also provided. These correction factors are based on rigorous computer simulation. The accuracy of this simple method is also compared with the rigorous computer simulation results obtained by a commercial process simulator and reliable experimental data, where excellent agreement has been obtained.