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Any need that design pressure of claus unit to be designed for deflagration? Since, the air is limited. Any incidents from your past experiences to share if we don't design for?

Love the way u explain

Good job

Good job

Awesome content

Very happy to see this type of content in the platform. The video was pretty useful, thank you man!

Can I apply a job in ur company?

Awesome content

Excellent 2 part video package, I love the energy! Something you may find interesting and may lead to an increase in HSAS cases.... We (Qa3) have observed oxygen being introduced into gas processes via flare gas recovery (FGR) systems. FGR systems are reintroducing gas from low pressure systems, which was histroically sent to flare, back into the gas process. A major proportion of this gas will be blanket gas (nitrogen) which is typically generated offshore from the air using membrane technology. This technology is not removing all the oxygen and hence oxygen is now being introduced into the gas process; therefore, amine units may now begin to see increased concentrations of oxygen! And a second thought on this. You mention surge drums could potentially suck air back into the process (introducing oxygen) if a blanket gas is not used. Bang on, but worth considering that the blanket gas may also contain potentially 1-2% oxygen. Another potentail source of oxygen ingress into amine units. Thanks again guys, check us out if you want to chat through our above thoughts. (www.qa3.co.uk)

Thank you for this valuable content! But sir can you please cover the part of the cracks root cause in reboilers! thank u or if you have any useful documents! thanks in advance

Please I need your help. I work in a refinery and our Gas con unit has LPG amine absorber and the LPG is all liquid. Won't there be forming or how does these design works

thank you :=)

very interesting, please correct the slide shown at 12.20 from contaminated Amine to cont Hydro

Dear Sir, can you give us the minimum value of lean amine loading, that we can monitor lean amine loading higher that can form a Pyrrhotite film layer ?? how much [H2S] in lean amine is enough. ?

Thanks for nice explanations. Whether COS gets converted to sulphur in TGTU reactor?

@Ben, do we have expertise in CO2 dehydration using TEG solvent and material selection by analysing corrosion mechanism.

Hi, is there any chance to get heat stable salts in SELEXOL

Hi! Why you dont put DEA for CO2 removal as a common case?? Thanks

Good information Ben. I attended some of your F2F courses as a part of Amine Experts training at McMahon plant in norther British Columbia (Fort St John). During the 3 year turnaround we used to clean the garbage out of the flash tank. Need to be careful about the present of iron sulfide while cleaning any part of the amine network. Based on my experience, residence time can be difficult to specify, but 25-30 min is reasonably good depending upon the quality of the incoming HC gas. More the better if there are some free HC liquid coming with the gas, but the design concept varies. Best practice - clean the sludge during the turnaround. Thanks for the table of residence time vs HC particle size.

Hi, very nice info. We have a concern in sru train Sulfur storage tank. We dont have drain option to empty out and drain completely during T&I. We have to pump out using sulfur transfer pump to the bottom most of the level to main sulfur storage tank .our project team belives it can be done smoothly using pump to empty out tank completly.is our understanding corect.that it can be done smoothly. What kind of safety concerns might arise if empty out completly using transfer pump...

Do you have a flow rate for hot oil reboilers? Our hot oil operates at 177 deg. C

So informative! Query: Gas injector wells near choke valve always see sulfur deposition downstream of choke valves. Gas has acid gases such as H2S, CO2 etc. Similar deposition also seen with Dry Gas Seal for gas compression system as well. Any way we can prevent it? Thanks.

if the HSAS content increases, it will cause the Hydrocarbon in CO2 Venting to also increase. My question is whether HSAS can cause an increase in the solubility of Hydrocarbons in amine solutions?

Can high HSAS cause loss of Hydro carbon in the vents?

Me sattar from Pakistan. I must say excellent videos that I was searching for. I am working at the amine plant where we are facing frequent reboiler tubes failure. The second is blackish TEG colour. Plant is designed 100 MM with stream 24%CO2 and 20PPm h2s.which video is for TEG.regards.

Excellent

Hi Ben, in our stripping tower we have a huge problem due to flooding and this issue starts sometimes in the middle or in the bottom, what could be the root cause of this? In addition, the amine looks very well (clear and a very pale green) inside the tower's bottom. However, we took a sample from the reboiler feed ( is a once-through reboiler) and in that point the amine looks green cloudy.

kindly upload more videos related to gas processing and equipments

Ty! I’m a student (ChemE). I’ve been watching your series to get some industry info. Very informative

Que buen video.

What is max allowable HSAS?

More useful information But if we go with fouling resistant trays, we face debris coming to the bottom and fouling reboiler and feed bottom exchangers. Any modification suggested in tray bottom to collect these debris

Could you please talk about the liquid sulphur volume expansion and associated line rupture?

good evening, i need ur experience in this field about sulfur handling and crushing sulfur , we have crushing sulfur operation inside gas plant we use heavy equipment's to crushing and loading sulfur , during crushing activity there is fine dust collecting inside the engine of equipment's spicily the dozer how we can prevent the catch fire or explosion during the crushing activity , is this operation save using dozer for crushing sulfur .

Keep these coming. Hugely informative.

Please keep these videos coming.

Look forward to more videos. Keep them coming.

Excellent explaination!

where can I see part 2

Thank you very much for very nice explanation

thank you very much for excellent explanation..

Very nice topic... excellent explain..thanks

Ben, good explanation unfortunately i haven't work in Amin unit but Iam working in merox unit to produce jet fuel we are using Air and caustic in our process to remove TAN but sometime foam is forming still i dont know source of this foam how it is formed regarding to your tutorial video u mention it is because of some contaminates so plz can u specify contaminates compositions to be more clear to me

Thanks for the video, really useful. I had a question. Is there any evidence of increase likelihood of amine SCC on the lean amine circuits when you operate at low amine loading?

What are the options available to reduce bicine levels without impacting heat stable salts level below a point which increases reboiler duty. What are the best methods to reduce bicine levels

Great

anyone using benfield system for c02 removal need some information

Great thanks Sir

‏Why Amine concentration is not 100% in BAGRU, ARU & TGTU?

Thank you for video! What about of affect of remaining SO2 from Como reactor?