If you are going to be at atmospheric pressure, then you will probably be in the 60-70% glycol range, but if you can run with low pressure, then a 50% solution would be best. These blends are the most common, and in use for most common applications. At 140 C, the equilibrium boiling pressure...
I would suggest an EG based heat transfer fluid for your system. It sounds like a fairly typical cooling system, so nothing exotic should be required. What do you anticipate your highest glycol temperature being? That would determine your water content.
There are also more advanced corrosion...
What temperature do you need? EG has the best properties for heat transfer, but has a lower degradation temperature than TEG, it is roughly the same as DEG.
EG/DEG can degrade at temperatures >330 F (165 C), TEG degrades over 405 F (207C).
I would use EG ot TEG, not DEG. Of coure it should...
QCorr,
Have you experienced foaming with high pH or is this something you haev heard/read/etc..? Pure TEG had a pH in the 7-8 range, it is my experience that operating with a higher pH does not mean for certain that you will experience foaming, rather it is an indication that you have some...
Injecting into the piping prior to the coalescer is the way I have seen it. Make sure that you are using DI water or steam condensate to prevent contamination of downstream processes from impurities in raw water.
I have also seen in some cases that the corrosion inhibitors and other production...
Maybe lets try to understand the issue at the heart of the matter.
Why do you require ongoing pH monitoring and adjustment? Is it a sour gas that you are treating? Is there oxygen in your gathering system that is degrading the glycol?
We have dealt with many sour dehys that have ongoing pH...
I dont think a pH probe would work in this service because to accurately measure pH of TEG, it has to be diluted with water (usually ~50% water).
Andrew Lechelt
Technical Support Engineer
Quadra Chemicals
www.quadrachemicals.com
Most manufacturers would recommend that you install a coalecser or other high efficiency separator in addition to the slug catcher. The slug catcher will stop the large amount of liquids that come in from the field, usually with pigging, but wont necessarily stop fine liquid droplets that are...
As mentioned above, contacting the amine manufacturers (or vendors, depending on where you are) would be best. Which amine you choose would be largely dependant on your treating pressure, which you did not specify.
For a bulk CO2 removal application, I dont think that DGA would be the best...
I have much more experience with Sulfinol than with Selexol. Certainly selexol would be less expensive than Sulfinol in terms of CAPEX/OPEX because of the flash regeneration capability, that said however, I have not run across any Selexol plants treating a sour gas stream (in Westen Canada), so...
Commercially available simulators generally do not work for propietary amine formulations, as the manufacturers do not wnat the ingredients for their blends to be known to the public. Not all aMDEA blends are the same, so a commercial simulator would have to know the ingredients in the blend...
At the Laurance Reid Gas Conditioning Conference this year in Oklahoma, there was a very good presentation on iron sulfides put on by Ben Spooner of Amine Experts. If you contact him though their website, he may be able to provide some help.
www.amineexperts.com
Andrew Lechelt
Technical...
I am looking for information and operating experience with different types of activated carbon. Specifically the advantages/disadvantages of lignite based carbons vs. bituminous based carbons.
From what I understand, lignite carbons have a lower bulk density and a higher ash content than...
It can still be a problem with MDEA, as it can be with any amine. I would say that it would less common with MDEA because of the bicarbonarte reaction in MDEA is slower, so this reaction is more spread out in the contactor. With primary and secondary amines, the CO2 reacts directly with the...
Better a late response than never?
Everything else being equal, EG losses will be higher than TEG losses because of vapour pressure differences.
On a more practical thread though, you are correct in a way by saying that the separation efficiency in the refrige LTS is not as efficient as a...
GPSA databook, figure 21-3.
For H2S:1040-1210 kJ/kg
For CO2:1325-1390 kJ/kg
Andrew Lechelt
Technical Support Engineer
Quadra Chemicals
www.quadrachemicals.com
The max temperature in the contactor should generally be less than about 195F (90C). If you excced this temperature, because of the exothermic raction mentioned in the post above, corrosion in the contactor can become a major concern.
Common fixes to high contactor bulge temperature is...
Easiest solution is to burn it. Send it to the flare system at the plant. The flare KO should take care of the condensing water vapours in the line. You could also have a vent tank separator immediately off the regen O/H to get rid of the condensing water sooner.
Andrew Lechelt
Technical...
I cannot quantify the amount of C1 adsopbed by the glycol, but I do know that it is relatively small, assuming that the contactor is in good mechanical conditions (chimney tray, valves, downcomers, LCV controls, etc).
ThnikPad mentioneda very good point in BTEX emissions. BTEX is a much...
General practice for TEG dehydration is to maintain a ~5C temperature difference between the inelt gas and the lean glycol. The reason for this is to prevent any condensation of hydrocarbons from the vapor phase into the liquid phase in the contactor. So this means that with 55 C gas, your...
