Projected diesel shortages could become a crisis if winter conditions are severe, potentially knocking out already strained power grids. What strategies should refiners rely on to increase distillate-range material?

How can the refining industry supply the aviation industry’s growing demand for sustainable aviation fuel (SAF)? What are the most efficient pathways?

In hydrotreater, what is the difference between direct desulphurization reaction route and indirect desulphurization reaction route for HDS reactions?

Is it type of catalyst(NiMo/CoMo) or the nature of the sulphur molecule that decides the reaction route of HDS reactions?

What is the difference between type1/type2/brim/Hybrim catalysts??

What is Direct and Indirect desulphurization route in HDS reaction in hydrotreaters, what factors affects the routes or pathways?

Is there any relation for catalyst selection and route preference for HDS? How does route or pathway makes any difference in final product s specification?

For Diesel hydrotreaters. How to finalize the catalyst from only CoMo & only NiMo and combination of NiMo/CoMo? Why is it said to be that NiMo catalyst consumes more H2 than CoMo catalyst?

What are water partial pressure & chloride partial pressure in the fixed bed catalyst of Naphtha Reforming Unit ? And how can be controlled ?

What is the best MOC for the NMP recovery and Dehydration portions of a Solvent Extraction System? We are finding that acid in the feed oil concentrates in the recirculating NMP and that this is degrading the 304SS process vessels. Is 316SS a good choice or will we need to go to more exotic alloys? The recirculating NMP can hit a pH of 4.0 and sometimes down to 3.7.

Are there any DCU units that processes more than 50%wt of SDA in fresh feed? If so, do you have any problems with increased foaming or fouling?

What's the philosophy of desalting system in Crude Distillation Unit, with respect to High Voltage & Demulsifier?

What is the main role of support material of the hydrotreater catalyst CoMo/NiMo? Does Support material participate in the hydrogenation reactions for HDS/HDN/HDA?

Hydrotreater catalyst at times said to be acidic and at times to be neutral as per the documents, which is true? Acidic nature for the catalyst is due to catalyst material or due to support material? Kindly guide.

What are the other methods to reduce feed foaming in DCU reactor, apart from the use of anti-foaming agents, increasing pressure and temperature? 

How does quantity of HP steam (34kgf/cm2) to strippers of hydrotreaters (10-11kgf/cm2g) for removal of H2S is finalized? What is the basis for it?

1. In any Hydrotreater unit, it is observed from our Material Balance sheets, that H2 dissolution is more in Hot HP Separator liquid than in Cold HP Separator liquid, even though the temperature is high in HHPS with marginal high pressure on the vessel compared to CHPS? Why is it so?

2. It is observed that Diesel Hydrotreater HHPS H2 dissolution is found to be on higher side compared to VGO Hydrotreater HHPS H2 dissolution, even though both pressure and temperature at HHPS of Diesel hydrotreater is less than VGO hydrotreater? Why is it so?

In Hydrotreaters for Stripping of H2S from Hydrocarbon stream, Naphtha Hydrotreater unit uses simple steam reboiler at the bottom of the stripper,  whereas Diesel and Vacuum Gas Oil hydrotreaters uses direct steam injection in strippers. why? Why can't we use reboiler system in Diesel and Vacuum gas Oil hydrotreaters strippers instead of direct steam injection?

In our Hydrogen plant designed by KT, we have 2 steam drums and during every start up, we face severe hammering in both steam drums intially. I worked before in other Hydrogen plants and have never experienced such hammering?

I am currently working on a project about chlorination processes and mechanisms. One day I was reading about direct chlorination of ethylene through the process called "Low Temperature Direct Chlorination" which was developed by Vinnolit. There is no more information about the catalyst, or newest technological development of the said company. The patent (US20170267610A1) describes the newer process and its ingenious configuration. "Low Temperature Direct Chlorination" astonishes me and I'd like to learn more about it.

Since all of the EDC producers in my country are high temperatures, I was wondering if someone could inform me about the catalyst of this process, or the mechanism of such a catalyst in commercial applications or promising articles about it.

In Diesel Hydrotreater, what factors decides to go with Hot HP Separator / Cold HP Separator / Cold LP Separtor configuration or only CHPS/CLPS configuration or only CHPS configuration? 

Our Vacuum gas oil hydrotreater feed blend has got three feeds,  Light Vacuum Gas Oil/Heavy Vacuum gas oil from VDU & Heavy Coker gas oil from Delayed coker unit (Blend distillation IBP to FBP in the range of 260 to 600 degC and specifically Temperature to distill 5% volume is approx at 350degC). After hydrotreating, in the fractionation column we draw Diesel and Naphtha. As the feed doesn't contain Naphtha and Diesel cuts specifically & being hydrotreater but not hydrocracker, how does generation of Naphtha and Diesel in the fractionation column is happening (Both product streams combined Approx 14%)? Is it purely by thermal cracking at the hydrotreater conditions of Vacuum Gas Oil? How should I understand this?

Importance of maintaining specific range of temperature to Hot HP separator in hydrotreating units?

Relation of H2 gas and salts ie: Ammonium Bisulfide and Ammonium chloride  solubility with temperature of the gas/liquid mixture upstream of Hot HP separator?

Our Diesel Hydrotreater feed is containing CCR 0.01wtppm and Total Aromatics of 31.5%, if CCR of feed is in such low values, indicating coke forming tendencies of feed is very low, then what causes coking on diesel hydrotreating catalysts?

Our Vaccum gas oil hydrotreater feed contains CCR 0.85% and Asphaltenes <300ppm and product CCR is <500ppm. The route for reduction of CCR in VGO hydrotreater is by formation of coke on catalysts or is there any other mechanism of reduction of CCR without coke formation?

What is the meaning and importance of analyzing wt% H2 content in Vacuum gas oil feed and product?

Our VGO hydrotreater product specification is said to have min 1.0% Delta hydrogen content w.r.t feed design value of 11.8wt%. If feed wt% H2 content is more than feed design value, will it make any difference to VGO product %wt H2 content?

What exactly causes coking on Diesel and Vaccum gas Oil hydrotreating catalysts (treating Crack and Straight run feeds)? 

Spent caustic after treating LPG in Continuous film contractor is regenerated in oxidizer column using process air and heat followed by removal of disulphide oil with solvent hydrotreated Naphtha. Offgas generated in oxidizer column are burnt in heater. From Past few year, problem of chocking in overhead line of oxidizer column is found which is disturbing overall regeneration process. However, replacement of overhead line was carried out for one time, but after 1-1.5 years, same chocking problem is occuring. Any observation or experience regarding situation and troubleshooting to control and mitigate?

What is the purpose of Multi-catalyst Bed philosphy in hydrotreating of Diesel and Vaccum gas oil cuts?

Besides this, for Multi - Catalyst bed configuration, some x or y % of HDS / HDN / HDA happens in each bed, before getting admitted into next catalyst bed. How and who (factors) controls that x or y%?