Abstract:
The invention relates to a preparation method for hydrocarbon cuts, said method comprising: a) providing a hydrocarbon feedstock originating from ethanol having an initial boiling point and a final boiling point in the range from 20 to 250° C. and comprising: from 20 to 60% by weight of aromatic compounds; from 20 to 60% by weight of non-cyclic paraffins; and from 2 to 20% by weight of naphthenes, with respect to the total weight of the hydrocarbon feedstock, b) optionally, a step of hydrogenation of the hydrocarbon feedstock originating from ethanol provided during step a) in order to obtain a hydrogenated hydrocarbon feedstock; c) a distillation step (i) of the hydrocarbon feedstock originating from ethanol during step a) or (ii) of the hydrogenated hydrocarbon feedstock according to step b), in order to obtain at least one hydrocarbon cut having a difference of less than 100° C. between the final boiling point thereof and the initial boiling point thereof.
Abstract:
The invention is a process for dearomatization and isomerization of a feedstock having less than or equal to 10 ppm by weight of sulphur, the process comprising: Hydrodearomatizing the feedstock at a temperature ranging from 150 to 220° C. and at a pressure ranging from 20 to 150 bars, in order to provide a dearomatized product; Hydroisomerizing the dearomatized product at a temperature ranging from 250 to 320° C. and at a pressure ranging from 40 to 60 bars in the presence of a catalyst based on platinum or palladium, in order to provide an isomerized product; Hydrodearomatizing the isomerized product at a temperature ranging from 150 to 220° C. and at a pressure ranging from 20 to 150 bars, in order to provide an isomerized and dearomatized product.
Abstract:
The invention is a process for producing a white oil having an initial boiling point of at least 250° C., the process comprising a step of catalytically hydrogenating a base oil feedstock at a temperature of from 120 to 210° C., at a pressure of from 30 to 160 bars and a liquid hourly space velocity of 0.2 to 5 hr−1, the base oil feedstock comprising less than 5 ppm by weight of sulphur.
Abstract:
In accordance with one or more embodiments of the present disclosure, a method for producing aromatic compounds from pyrolysis gasoline comprising C5-C6 non-aromatic hydrocarbons includes aromatizing the pyrolysis gasoline in an aromatization unit, thereby converting the C5-C6 non-aromatic hydrocarbons to a first stream comprising benzene-toluene-xylenes (BTX); hydrotreating the first stream comprising BTX in a selective hydrotreatment unit, thereby producing a de-olefinated stream comprising BTX hydrodealkylating and transalkylating the de-olefinated stream comprising BTX in a hydrodealkylation-transalkylation unit, thereby producing a second stream comprising BTX, the second stream comprising BTX having a greater amount of benzene and xylenes than the first stream comprising BTX; and processing the second stream comprising BTX in an aromatics recovery complex, thereby producing the aromatic compounds from the pyrolysis gasoline, the aromatic compounds comprising benzene, toluene, and xylenes.
Abstract:
This disclosure relates to new processes to produce high paraffinic diesel from crude oil, such as tight oil from the Permian basin. This disclosure also relates to high paraffinic diesel compositions and high paraffinic diesel blends.
Abstract:
A hydrogenation method and distillate two-phase hydrogenation reactor in which the size of an upper space of the reactor is greater than that of a lower catalyst bed part. The reactor comprises 2 to 4 catalyst beds. An inner component for gas replenishment and for stripping a liquid-phase stream containing impurities is arranged between at least one adjacent catalyst bed and comprises a separator plate and exhaust pipes. The separator plate is provided with multiple downcomer through holes. The separator plate is connected with a plurality of exhaust pipes. The exhaust pipes are vertically arranged above the separator plate. The top parts of the exhaust pipes are in contact with the lower part of the upper catalyst bed.
Abstract:
A process for hydrogenating a low sulphur blended feed into very low sulphur and very low aromatic hydrocarbon fluids having a boiling point in the range of from 100 to 400° C. and a boiling range of not more than 80° C., the low-sulphur blended feed including a mixture of: i) a hydrocarbon cut originating from a gas-to-liquid process with ii) at least one selected from the group consisting of a hydrodeoxygenated hydrocarbon cut obtained from biomass, a gas condensate, a hydrocarbon cut of fossil origin and mixtures thereof; the process including the step of catalytically hydrogenating the feed at a temperature from 80 to 180° C. and at a pressure from 50 to 160 bars.
Abstract:
Methods are provided for hydrotreating high nitrogen feeds with improved results for nitrogen removal, aromatic saturation, and/or sulfur removal. The method includes hydrotreating the feed with a supported hydrotreating catalyst followed by a bulk metal catalyst, the hydrotreated effluent of which can be suitable for use as a feed to an FCC reactor.
Abstract:
A process for hydroprocessing hydrocarbons in a combined targeted pretreatment and selective ring-opening unit wherein the targeted pretreatment comprises at least two stages in a single liquid recycle loop. The process operates as a liquid-full process, wherein all of the hydrogen dissolves in the liquid phase. Heavy hydrocarbons and light cycle oils can be converted in the process to provide a liquid product having over 50% in the diesel boiling range, with properties to meet use in low sulfur diesel.
Abstract:
Integrated processes for upgrading crude shale-derived oils, such as those produced by oil shale retorting or by in situ extraction or combinations thereof. Processes disclosed provide for a split-flow processing scheme to upgrade whole shale oil. The split flow concepts described herein, i.e., naphtha and kerosene hydrotreating in one or more stages and gas oil hydrotreating in one or more stages, requires additional equipment as compared to the alternative approach of whole oil hydrotreating. While contrary to conventional wisdom as requiring more capital equipment to achieve the same final product specifications, the operating efficiency vis a vis on-stream time efficiency and product quality resulting from the split flow concept far exceed in value the somewhat incrementally higher capital expenditure costs.