Treatment With Hydrotreatment Processes TRIZ Cases

Supercritical water treats hydrocracked unconverted oil to remove heavy polynuclear aromatics, cutting coke precursors and extending catalyst life.

Depentanizing pygas before hydrotreatment preserves isoprene, piperylene, and cyclopentadiene while cutting hydrogen use and coke formation.

Separating feed into paraffin-rich and paraffin-poor streams enables hydro-processing that raises lube oil viscosity index while lowering cost.

Filtration, aromatic blending, and hydrotreating stabilize hydrocracker resid, cut sulfur and sediment, and help meet IMO 2020 fuel oil specs.

Independent reaction trains and tuned hydrotreating conditions turn waste oils into on-spec Group III/III+ base oils without sacrificing yield.

Tailored demetallization, hydrotreatment, and hydrofinishing raise used oil yield while matching Group II/III blending viscosity and stability.

Co-processing vacuum gas oil with pre-treated used oil raises lubricant-range yield and delivers Group II/III base stocks fit for blending.

A two-stage slurry reactor route raises BTEX yield from pyrolysis oil by converting multi-ring aromatics under milder catalytic conditions.

A staged pretreatment and catalytic core process cuts sulfur and vanadium in distressed fuel oils while preserving HMFO viscosity and density.

Group VIII catalyst hydrogenation lowers aromatics and naphthenes in re-refined lube oil to produce Group III base oil with better cold flow.

A Pt/KL zeolite catalyst with Group IIA or rare earth modifiers converts C9+ aromatics to BTX with higher yield, conversion, and selectivity.

Pretreatment, UCO blending, vacuum distillation, and catalytic dewaxing turn impurity-rich waste lubricant into stable high-quality base oil.

A three-zone hydrogenation reactor with gas-liquid separation improves mass transfer, cuts hydrogen use, and enables two fractions in one unit.

Thermal treatment converts mixed artificial turf into hydrocarbons, while density separation removes solids and heavies for cleaner downstream feed.

Selective organic-solvent extraction removes biolubricants before hydrofinishing, helping waste oils yield Group III lubricant bases with lower energy use.

Controlled hydrogenation and fractionation limit aromatic content and by-product formation while preserving yield in high-purity white oil production.

Hydrotreating, hydrocracking, catalytic dewaxing, and hydrofinishing produce heavy base oil that remains haze-free at 0°C.

Sequential coagulation, centrifugation, distillation, and solvent extraction remove impurities before hydroprocessing waste oil into VI 130+ base oil.

Pretreatment and hydroprocessing turn waste oil into Group III+ base oil.

Low- and high-pressure hydroprocessing with catalytic dewaxing reduces viscosity and raises viscosity index in naphthenic brightstock.

Countercurrent hydrolysis, resin purification, and activated carbon raise green diesel and biokerosene yields while extending catalyst life.

This process combines ethanol dehydration, MTO, and oligomerization to convert carbon oxides into renewable jet fuel and diesel.

This hydrogenation process recycles liquid and gas between reaction zones to reduce pressure losses and downtime during campaign changes.

Switchable guard zones divert heavy feed to downstream beds, extending catalyst operating time while reducing metal deposition and clogging.

Reboiled stripping columns recover LPG hydrocarbons via sponge absorption, eliminating steam usage and reducing energy consumption.

A staged hydrotreating and hydrocracking process separates diesel from lighter materials before the hydrocracking reactor to preserve product yield.

Liquid quench absorbs hydrogen from separators to enhance catalyst contact, resolving low hydrogen transfer rates that cause rapid deactivation.

Segmented hydrotreating trains maintain continuous feed to fluid catalytic cracking units during catalyst replacement cycles.

Separating aromatic-rich and lean fractions allows differential processing that reduces operating severity while improving mid-distillate yield.

Integrated prefractionator combines deethanizer and splitter functions into one column, eliminating separate units and reducing steam consumption.

Oxidized olefin wax modifies crystalline structure in metallocene polyethylene, reducing moisture permeability for packaging applications.

Neural network models predict impurity removal amounts in chemical processes, reducing catalyst replacement costs by minimizing measurement system complexity.

A hydroprocessing method uses a high solubility blending number utility fluid to upgrade pyrolysis tar under elevated pressure and temperature conditions.

Pretreatment removes acetylene, sulfur, and fine particles to prevent Ag membrane clogging during olefin separation.

A split shell stripper vessel fractionates naphtha streams to remove H2S while preserving olefin content.

Dynamic temperature control based on effluent sulfur content enables continuous processing of varying feedstocks without interstage separation.

Multi-stage reactor separates hydrogen sulfide to maintain catalyst activity and achieve ultra-low sulfur diesel production.

Segments diesel feed into distinct hydrotreating stages to remove refractory sulfur species while maintaining NiMo catalyst activity.

Segmenting olefin feed streams controls reactor temperature distribution, resolving catalyst performance issues in desulfurization.

Fractionating gasoline into an intermediate cut for selective hydrodesulfurization.

Acetone and acetonitrile dissolve mutagenic compounds from aromatic extracts, eliminating repeated processing cycles that raise production costs.

Low severity deasphalting combined with catalytic processing produces lubricant base stocks from vacuum resid feeds.

Sulfur-modified molybdenum catalyst purifies waste plastic pyrolysis oil while preventing ammonium salt formation and catalyst deactivation.

A hydrogen donor solvent supplies hydrogen to a mixed stream during second reactor hydrotreating, preventing catalyst deactivation and coke formation.

Distillation separates aromatic bottoms to reduce benzene content below three percent volume.

Low sulfur feedstock processing minimizes cracking by-products and boosts yield while maintaining purity standards.

Mixing petroleum cuts with inert diluents reduces aromatic content during catalytic hydrogenation.

Solvent deasphalting removes asphaltenes via virgin crude intermediaries, reducing precipitation and capital expenditures in heavy crude processing.

Hydrotreating removes olefins before zeolite-catalyzed aromatization converts paraffins into BTX, increasing aromatic recovery yields.

Segmented process converts pyrolysis gasoline C5-C6 non-aromatics to BTX, increasing aromatic recovery despite added treatment steps.