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What are you trying to model? Typically there are two main uses for glycol in a gas plant: a) If its MEG injection for hydrate control then the mass of gas will rule for the chiller duty required and the glycol temperature variation will have a minor effect on the overall refrig compressor horse...

Sample cocks are probably still the only really accurate way but depending on the emulsion we have used capacitance probes (Agar)

Its also a matter of blocking the flow - draw out to scale a 2" sch 40 or 80 pipe with a ¾ or 1" TW in it and see how much Xsectional area is left

The steam boiler people have guide lines for this I believe Struthers and Thermotics used numbers like rhoV²= 27,000 to 40,000 (SI units) with 5D bends instead of LR els, but the usual safe route is per API 14C which I believe uses a consevative rhov²<=10,000 english units

We have used elevated incinerators to dispose of H2S and BTEX in the TEG still effluent (overhead line from still sloped back to the still from the nozzle on the vertical incinerator so any condensed water runs back) with good results, and this is probably your best approach. We used fuel gas...

I think Kaverner also have designs for liquid sulphur burnes

Not a problem if the recycle gas is adequately cooled and the recycle valve is controlled by the suction pressure controller. If its wet natural gas then ensure the JT cooling across the recycle valve doesn't cool the stream below the hydrate temp - may have to modulate the temperature with hot...

If you have a hydrogen plant whach out for NH3 in the steam - this will rule out copper. Either carbon steel or 304/316 SS is OK