Hydrocarbon Oil Cracking TRIZ Cases

Pre-mixing heavy oil with carboxylic or ester additives cuts preheater fouling, improves catalyst dispersion, and limits coke precursors.

Premixing heavy oil with an organic additive forms an in situ catalyst that cuts preheater fouling and improves hydroconversion of low-quality feedstocks.

Stacked collection and distribution trays improve quench-zone mixing while reducing interbed space, reactor size, and catalyst loading loss.

A single-stage hydrocracking and hydroisomerization route raises jet fuel yield while preserving cold flow properties from paraffinic feedstocks.

Controlled HPNA adsorption on hydrocracking catalyst acid sites shifts cracking toward middle distillates while limiting over-cracking.

Coke production byproduct acts as a hydrogen donor to upgrade heavy oil with less coke formation and lower added hydrogen pressure.

Internal water injection and rotated lattice mixing improve hydrothermal polymer conversion by speeding mixing and limiting pressure drop.

A single reaction stage combines hydrocracking and hydroisomerization to process sustainable paraffins into specification-ready jet fuel and base oil.

This single-stage hydrocracking process opens at least 95 vol% of feed rings, producing an aliphatic effluent for light olefin production while addressing fouling and coking.

A two-stage process recycles unconverted residue through slurry hydrocracking to increase distillate yield, exceed 97% conversion, and reduce pitch.

See how staged hydrocracking sends unconverted residue to a slurry reactor, increasing light distillate yield while reducing coke-related fouling.

Recycling hydrocracked pitch residue in a slurry hydro-conversion reactor raises conversion above 97% while reducing pitch yield and fresh catalyst use.

A continuous high-rate hydrothermal reactor uses short residence times and rapid quenching to improve fuel conversion and limit fouling.

A two-stage LCO process combines hydrofining, selective conversion, and low-pressure saturation recycling to raise aromatic yields.

An extruder, melt filter, and degassing unit prepare mixed polymer waste for pyrolysis without mechanical sorting.

Hydrocracking and catalytic dewaxing improve oxidation and low-temperature performance.

Integrating oxidized disulfide oil by-products into refinery hydroprocessing converts waste streams into valuable alkanes while eliminating disposal challenges.

Segmented catalyst bed injection controls exothermic temperature spikes during mixed oil hydroconversion, extending unit service life.

Dual circulation channels in the inner liner ensure uniform temperature distribution and prevent wall coking during suspension-bed hydrogenation.

A fluid mixing apparatus integrates collection, mixing, and distribution zones to enhance catalyst bed flow.

A bio-oil hydroprocessing reactor manages heat release by segmenting feed introduction across multiple catalyst beds.

Fluid catalytic cracking transforms triglycerides into aromatics, maintaining the -40°C freezing point during hydrotreatment.

Heavy reformate conversion utilizes cross-process exchangers to reduce energy consumption while maximizing para-xylene yield and minimizing benzene byproducts.

Ebullated bed hydroconversion process segments heavy feed and recycles unconverted vacuum gas oil fractions to boost gasoline production.

Segmenting hydroprocessed effluent into multiple strippers reduces heater duty by forty percent while lowering capital costs through optimized column design.

Delaminated SSZ-70 zeolite catalyst segments micrometer-scale crystals into ultrathin layers to eliminate mass transfer limitations in hydroprocessing reactions.

Segmented ebullated bed and fixed bed reactors upgrade residuum hydrocarbons, reducing asphaltenic sediment formation in downstream processes.

Dissolving hydrogen in the liquid feed stream eliminates gas-phase limitations, allowing liquid mass flux above 5000 lb/hr·ft2 without excessive pressure drop.

Dissolving hydrogen in liquid phase feed reduces vapor transfer resistance, lowering consumption and coke formation in hydroprocessing.

Segmenting the inlet pipe and adding a convex knob breaks high-velocity streams to eliminate temperature differences in three-phase reactors.

A pitch hydrocracking reactor converts heavy asphaltenic pitch into distillate hydrocarbons using spent catalyst and hydrogen.

A hydrocracking process upgrades heavy hydrocarbons into light and middle distillates using specific temperature and pressure ranges.

Separation zone with noble metal catalyst reduces operating pressure while saturating aromatics, lowering capital and operating costs.

Segmenting crude streams via a vacuum flasher reduces reactor volume and hydrogen consumption by excluding unreactive residue components.

A split flow hydrocracking process divides gas oil streams to optimize reaction severity across parallel catalyst beds.

A slurry phase hydrocracking unit converts heavy feedstocks into lighter transportation fuels through integrated thermal hydrogenation.

Solvent deasphalting separates asphaltenes from heavy residues, reducing nickel and vanadium content in turbine fuel.

Segmented tubular risers maintain uniform flow across varying liquid levels, reducing coke formation and extending reactor run duration.

Segmented windows and branching structures distribute light fluid phases uniformly, eliminating dead zones and bypasses in fluidized beds.

A gas-to-liquids process co-processes biomass oil with natural gas using extracted hydrogen for hydroprocessing.

Organic additives in the catalyst precursor inhibit coke precursor formation, reducing equipment fouling and extending operational lifespan.

Removing hydrogenative metals from USY zeolite resolves overdesign inefficiencies, boosting API density and process effectiveness.

Merging pre-treatment with hydrocracking in one reactor eliminates nitrogen poisoning shutdowns while maintaining high reactor capacity.

Segmented contacting zones manage heavy metal deposits in hydrocracking systems, extending equipment run time and maintaining process efficiency.

A vacuum product fractionation column separates hot stripped hydroprocessed streams directly without atmospheric distillation.

Hot separator removes hydrogen sulfide from hydrotreating effluent before hydrocracking, resolving sulfur content limits in diesel production.

Segmented inlet conduits distribute liquid, gas, and solid phases uniformly to prevent catalyst deactivation and temperature spikes.

Segmented contacting zones with permutable separation units minimize catalyst consumption while maximizing heavy oil conversion rates.

A composite catalyst bed merges hydrotreating and dewaxing functions to balance exothermic and endothermic reaction heat.

Disintegrating aggregated iron-based catalysts restores surface area and catalytic activity in hydrocracking processes.