Gas Hydrate Inhibition
1. Depending on the size of methane/ethane/propane/CO2 (guest) molecules with suitable (high) pressure and (low) temperature conditions, if, different hydrate structures keep forming (s-I, s-II, s-H), then, how easy would it remain to capture the simultaneous co-existence of various hydrate structures (with different compositions) as a function of gas composition and PT conditions @ lab-scale towards characterizing a multi-component gas system?
2. Is there a standard procedure, whereby the type of gas hydrate inhibition technique (physical techniques: thermal-heating/depressurization/dehydration; chemical inhibitor techniques: thermodynamic hydrate inhibitors/kinetic hydrate inhibitors/anti-agglomerates) to be applied remain varying depending on the occurrence of hydrate blockage either @ upstream facilities; or @ downstream facilities?
3. Feasible to capture the time rate of change of clogging (the way, the hydrate film gets thickened gradually over time and eventually causing a reduction in pipe diameter) upon achieving an enhanced solid-liquid ratio of hydrate slurry resulting from an increased formation of hydrates @ lab-scale?
4. Leaving aside the problems associated with an oil-dominated system and high-water-cut-system, how exactly will we be able to differentiate the problems associated with gas-dominated system and condensate system towards protecting the pipelines from clogging up – upon the formation of hydrates @ lab-scale?
5. Any distinct difference observed @ lab-scale while conducting gas hydrate formation experiments @ following different temperature and pressure combinations? (a) 275 K & 3 MPa; (b) 275 K & 10 MPa; (c) 285 K & 3 MPa; & (d) 285 K & 10 MPa.
6. Albeit depressurization can(not) inhibit the formation of gas hydrates, would it remain feasible to deduce the threshold (maximum) length and pressure associated with the gas transport of pipe lines, whereby the line-depressurization technique still works successfully in the absence of causing hydrate plug’s velocity to get enhanced; and thereby, essentially avoiding the possible damage of pipeline structures of interest?
7. Leaving aside thermal heating associated with its expensive cost per unit km of pipeline length, would it remain feasible to dehydrate all the water in the gas stream towards gas hydrate inhibition?
8. Since chemical inhibitors try to mitigate/change the phase behavior of gas hydrates; then, at some point, won’t it adversely affect the smooth, continuous flow in the gas pipelines?
9. Where exactly dual-purpose gas hydrates and corrosion inhibitors remains very efficient than using KHI (PVP, PVCap) and THI (methanol/MEG) in oil/gas pipelines?
10. How easy would it remain to dissociate gas hydrates @ lab-scale using coupled effect of direct heating and depressurization given the fact that natural gas hydrates remain highly unstable and gets readily breakdown upon heating/depressurization?
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