What is needed for large-scale upcycling of plastic waste to valuable chemicals like polyethylene?

How are cross-functional teams achieving operational efficiency and process safety targets?

What areas of expertise are needed to mitigate constraints in plant/facility staffing levels?

How can fractionation upgrades be achieved without expensive metallurgical upgrades?

How can refiners overcome challenges during FCC fast pyrolysis bio-oils (FPBO) co-processing with vacuum gasoil (VGO)?

How to reduce sox emissions from FCC regenerator by changing which operating conditions..? Like Catalyst circulation reduction, combustor temperature reduction, ROT reduction etc.

Is it feasible to process slack wax in a delayed coker? If so, what are the potential benefits and operational challenges?

Regarding visual inspection of Vacuum Distillation Bottom Product of Used Oil Re-refining, the sample appears to be more viscous after heating, and less viscous on cooling! Is there an explanation for that?

What potential limitations might arise when attempting to reduce the coke drum pressure to the design values in Delayed Coker Units? Additionally, what types of investments might be necessary if we aim to further decrease the pressure?

How do you manage the pressure in the Fractionator within a Delayed Coker Unit? From what I understand, both the Fractionator and Coke Drum pressures are regulated by the inlet pressure of the Wet Gas Compressor. However, during drum switch operations, significant fluctuations in the Fractionator top pressure make it challenging to maintain stable control. Are there any control strategies or philosophies that could be applied to effectively manage the pressure in the Fractionator and Coke Drum in the Delayed Coker Unit in addition to inlet pressure control of WGC?

 How to prevent fouling in feed/effuent exchanger of sour water stripper unit?

How to prevent fouling in feed / effluent exchanger of hydrotreatement unit in refinery?

Are there any methods to reduce coker furnace fouling through chemical injection in furnace tubes .

If yes, how was the experience?

How can AI capabilities improve machinery performance challenges?

Our aviation kerosene silver corrosion test is good, but copper corrosion is bad. What is the possible reason for this situation.

There is any safe limit for chlorine for DCU feed?

Has any coker seen an effective Coker Furnace higher run length by Chemical injection.

If yes what were your observations?

Why should water boot be vertical? We want to implement water wash of overhead condenser, but 3 phase separator is bottleneck, esspecially water boot. We can not extend it verticaly, to get more residence time for water (space limitations). Potential option is to extend boot horizontaly - to increase its DIA to bi as wide as vessels, or to change boot with another smaller vessel, to provide residence time. Are this options even applicable or must hold on to already proven solution, like vertical boot?

What could be done for de-aromatization of uncoverted oil (UCO or off test) from hydrocraker unit? Could hydrotreating be effective or not? In the other words, is it possible to saturate PNA's (which they are in the UCO) by hydrotreating?

Our desalter is facing a rag layer issue when we process cabinda crude. The brine turns black. It seems like our current emulsion breaker can not solve this problem. Is there any ideas or recommendations?

What are types of Corrosion Inhibitor (Filmer) and neutralizing amine used in crude distillation units. What is the philosophy of their work and the concentration of injection?

How much sodium is the limit expressed in mg/kg that can be loaded into a Visbreaker system without causing excessive scaling or coking in the oven?

We have a black sludge formation at the interphase of naphtha and water in OVHD accumulator. But all the OVHD paramters like pH, Iron  and Chloride are normal. The crude unit has a partail condensation ovhd system and the black sludge is observed in the second boot (Cold reflux boot). There is a CI dosing in the accumulator upstream. What could be the reason for this sludge?

A TGT that uses a steam heater to raise the temperature is experiencing a drop in quencher pH after shutdown maintenance and startup. In this TGT, passivation was done at shutdown for shutdown maintenance, and pre-sulfurization was done at startup and startup. The TGT reactor has thermometers at the top, middle, and bottom, and since startup, the temperatures at the middle and bottom have been the same, indicating that the catalyst in the lower layer is losing activity. The operation to raise the pH of the quencher with caustic soda had to be repeated two to three times a day, and by raising the H2S/SO2 of the SRU upstream to 5, the SO2 leak from the reactor was reduced, and the quencher pH drop is now only once a week. No unusual operations have been performed. The catalyst has been in use for 10 years, which is not a short period of time, but we do not believe it is a period of use during which a rapid decline in activity occurs. If anyone has experienced similar problems or has knowledge of the possible causes of the problems, it would be helpful.

With more emphasis on a CO₂ tonnage per dollar investment basis, which metrics matter in pursuing opportunities in petrochemicals or low-carbon fuels?