DE10297760T5 - Improved hydrocracking process - Google Patents

Abstract

A process for hydrocracking a hydrocarbonaceous feed comprising:
(a) a hydrocarbonaceous feed and hydrogen to a denitrification and desulfurization reaction zone at reaction zone conditions including a temperature of 204 ° C to 482 ° C, a pressure of 3.5 MPa to 17.3 MPa, an hourly liquid space velocity of the hydrocarbonaceous feed of 0.1 h ^-1 to 10 h ^-1 with a catalyst and an outlet from the denitrification and desulfurization reaction zone,
(b) transferring the effluent from the denitrification and desulfurization reaction zone directly to a hot high pressure stripper employing a hot hydrogen rich stripping gas to produce a first liquid stream comprising hydrocarbon compounds boiling in the hydrocarbonaceous feed zone and a first high pressure stripper Vapor stream comprising hydrogen, hydrogen sulfide, ammonia and hydrocarbon compounds,
(c) converting at least a portion of the first liquid stream comprising hydrocarbon compounds boiling in the hydrocarbonaceous feedstock to a hydrocracking zone containing a hydrocracking catalyst and at a temperature of from 204 ° C to 482 ° C, a pressure of ...

Description

background the invention

The Technical field to which this invention is attributable is Hydrogen treatment of at least one hydrocarbon-containing Feedstock. oil refineries often produce desirable ones Products such as turbine fuel, diesel fuel and other products, known as middle distillates, as well as low-boiling hydrocarbon liquids, such as naphtha and gasoline, by hydrocracking a hydrocarbon feed, for example, of crude oil or derive heavy fractions thereof. Most frequently hydrocracked feedstocks are gas oils and heavy ones Gas oils, from crude oil be obtained by distillation. A typical heavy gas oil includes one significant proportion of hydrocarbon components above Boil at 37 ° C, usually at least 50% by weight boiling above 37 ° C. A typical vacuum gas oil usually has a boiling point range between 315 and 565 ° C.

hydrocracking is generally done by treating the gas oil or other feed material, with a suitable hydrocracking catalyst under conditions increased Temperature and elevated To handle pressure in the presence of hydrogen is one thing To give a product for a the refinery wanted Contains distribution of hydrogen products. Working conditions and affect the hydrocracking catalysts in a hydrocracking reactor the yield of hydrocracked products.

It There is always a need for new hydrocracking methods, the lower ones Costs and higher Liquid product yields and products higher quality deliver. The present invention improves the economics benefits a low conversion per pass and demonstrates the surprising Advantages.

The US-A-5,720,872 B1 describes a process for hydrotreating liquid feedstocks in two or more hydrotreating stages housed in separate reaction vessels and in which each reaction step contains a hydrotreating catalyst bed. The liquid product from the first reaction stage is sent to a stripping stage at low pressure and the hydrogen sulfide, ammonia and other dissolved gases are stripped. The stripped product stream is then sent to the next downstream reaction stage where the product coming from this stage is also stripped to disperse dissolved gases and sent to the next downstream reaction stage, the product of which is also stripped to remove dissolved gases and to the next sent to the last reaction stage, the liquid product of which is stripped of dissolved gases and collected or sent for further processing. The flow of treated gas is in a direction opposite to the direction in which the reaction stages for the liquid flow are stepped. Each stripping step is a separate step, but all steps are contained in the same stripping container.

The US-A-3,328,290 B1 describes a two-stage hydrocracking process in which the feed is pretreated in the first stage.

The US-A-5,114,562 B1 describes a process in which a middle distillate petroleum stream is treated with hydrogen in series using two reaction zones in series to produce a low sulfur, low aromatic content product. The effluent from the first reaction zone (desulfurization) is cooled and introduced into a hydrogen stripping zone where hydrogen sulfide is removed along the head with a small amount of hydrocarbons present in the vapor at conditions prevailing at the top of the stripping zone. The bottoms stream from the stripping zone is reheated and introduced into the second reaction zone (aromatics saturation) containing sulfur-sensitive noble metal hydrogen catalysts.

The US-A-5,980,729 B1 describes a hydrocracking process in which a hydrocarbon feedstock and a hot hydrocracking effluent containing hydrogen are passed to a denitrification and desulfurization zone to produce hydrogen sulfide and ammonia, thereby purifying the fresh feed. The resulting hot, uncooled effluent from the denitrification and desulfurization zone is stripped in a stripping zone maintained at substantially the same pressure as the preceding reaction zone with a hydrogen-rich gas stream to produce a vapor stream containing hydrogen, hydrocarbon compounds which are present boiling at a temperature below the boiling range of the fresh feed, comprising hydrogen sulfide and ammonia, and a liquid carbon to generate hydrogen stream.

The US-A-5,403,469 B1 describes a parallel hydrotreating and hydrocracking process. Runoff from the two processes is combined in the same separation vessel and separated into a vapor comprising hydrogen and a hydrocarbon-containing liquid. Hydrogen is shown to be fed to both the hydrocracking zone and the hydrotreating zone as part of the feed stream.

Short Summary the invention

The The present invention relates to a catalytic hydrocracking process, the higher one Yields and quality the liquid Products delivers, especially higher Yields of jet fuel and diesel oil. The method of the present Invention provides the yield improvements in conjunction with a low conversion per pass without compromise on economy, so that low Capital costs can be realized through the use of the invention can. Furthermore can be an overall reduction of fuel gas and hydrogen consumption and the production of light final fractions.

One embodiment of the present invention relates to a process for hydrocracking a hydrocarbon feed. The process directs a hydrocarbon feed and hydrogen to a denitrification and desulfurization zone at reaction zone conditions including a temperature of 204 ° C to 482 ° C, a pressure of 3.5 MPa to 17.3 MPa, an hourly liquid space velocity of the hydrocarbon feed of 0.1 hour ^-1 to 15 h ^-1 with a catalyst and recovery of a discharge from a denitrification and desulfurization zone. The effluent from the denitrification and desulfurization zone goes directly to a hot, high pressure stripping zone using a hot, hydrogen-rich stripping gas, a first liquid stream comprising hydrocarbon compounds boiling in the hydrocarbon feed zone, and a first vapor stream Hydrogen, hydrogen sulfide and ammonia. At least a portion of the first liquid stream comprising hydrocarbon compounds boiling in the region of the hydrocarbon feed passes to a hydrocracking zone containing a hydrocracking catalyst and at a temperature of 204 ° C to 482 ° C, a pressure of 3.5 MPa to 17.3 MPa, an hourly liquid space velocity of 0.1 h ^-1 to 15 h ^-1 works. A hydrocracking zone effluent goes directly to the hot stripping device at high pressure. At least a portion of the first vapor stream recovered in step (b) and at least a portion of the hydrocracking zone effluent pass to an aftertreatment hydrogenation zone to saturate aromatic compounds. Condensing at least a portion of the resulting effluent from the post-treatment hydrogenation reaction zone produces a second liquid stream comprising hydrocarbon compounds having a boiling temperature below the boiling range of the hydrocarbon feed and a second vapor stream comprising hydrogen and hydrogen sulfide. The first, second and third portions of the second vapor stream are each returned to the hydrocracking zone, the denitrification and desulfurization zone and the hot stripping zone at high pressure. At least a portion of the hydrogen sulfide may be removed from the second vapor stream before being returned to the hydrocracking zone. The hydrocarbon compounds boiling at a temperature below the boiling range of the hydrocarbon feed are recovered.

at of the present invention, the hydrocarbonaceous feed, entering the first denitrification and desulphurisation zone serve as a first hydrocarbon feed. A second Hydrocarbon feed with a medium boiling point below that of the first hydrocarbon feed may be in an upper end of the hot, go at high pressure stripping means to serve as reflux, or may be in an intermediate position in the denitrification and Desulphurisation zone introduced to serve as a deterrent there. At least a part the second charge can work in the hot under high pressure Stripping device are evaporated and in the post-treatment hydrogenation reaction zone going to saturate aromatic compounds while reducing the quality of the hydrocarbon Outflow from the aftertreatment zone to improve. Alternatively or additionally at least a portion of the second hydrocarbon feedstock serves as a coolant and passes through at least part of the catalyst in the denitrification and desulphurisation zone for subsequent introduction in the hot, high pressure stripping device.

Short description the drawing

The Drawing is a simplified process flow diagram of one embodiment the invention.

Full Description of the invention

It it was found that higher liquid product yields and lower production costs can be achieved and in the above-described Hydrocracking are advantageous.

The Process of the present invention is particularly useful for hydrocracking of hydrocarbon oils, contain hydrocarbons and / or other organic materials, to produce a product containing hydrocarbons and / or others organic materials with a lower average boiling point and a lower average molecular weight. The Product can also have improved product features, such as improved Cetane number and improved black point, as well as reduced impurities, such as sulfur and nitrogen, to have. The hydrocarbon feeds that are a hydrotreating in the method of the invention can be subjected for example, all mineral oils and synthetic oils (for example shale oil, Tar sand products, etc.) and fractions thereof. Illustrative hydrocarbon feeds shut down those containing components boiling above 288 ° C, such as for example atmospheric Gas oils, Vacuum gas oils, deasphalted vacuum and atmospheric residues, hydrotreated or mild hydrocracked residual oils, coker distillates, straight-run distillates, with solvent deasphalted oils, pyrolysis oils, high-boiling synthetic oils, Return oils and Catcracker distillates. A preferred hydrocracking feed is a gas oil or a another hydrocarbon fraction of at least 50% by weight, and most commonly at least 75% by weight of it at temperatures above the endpoint of the desired Product boiling components, this endpoint in the case of heavy gasoline is generally in the range of 193 ° C to 215 ° C. One of the most preferred Gas oil feeds contains Hydrocarbon components that boil above 288 ° C, with the best results with feeds containing at least 25% by volume of the Components, which are between 315 ° C and 538 ° C boil, included. Also are petroleum distillates including at least 90% of the components in the range from 149 ° C up to 426 ° C boil. The petroleum distillates can be treated to both light gasoline fractions (boiling range for example 10 ° C up to 86 ° C) as well as heavy gasoline fractions (boiling range, for example, 86 ° C to 204 ° C) to produce. The present invention is particularly suitable for maximization the liquid product yield including middle distillate products.

At least one selected feedstock is introduced into a denitrification and desulfurization zone under hydrotreating reaction conditions. Preferably, the denitrification and desulfurization reaction conditions or hydrotreating reaction conditions include a temperature of 204 ° C to 482 ° C, a pressure of 3.5 MPa to 17.3 MPa, an hourly liquid space velocity of the fresh hydrocarbon feedstock of 0.1 h ^-1 to 10 h ^-1 with a hydrotreating catalyst or a combination of hydrotreating catalysts.

Of the Term "hydrotreating" or "denitrification" and desulphurisation ", as used herein means processes in which a hydrogen-containing Treating gas used in the presence of suitable catalysts that is primary active for the removal of heteroatoms, such as sulfur and nitrogen, and for something Hydrogenation of aromatics to be active. Suitable hydrotreating catalysts for the Use in the present invention are known conventional ones Hydrotreating catalysts include those that are at least a Group VIII metal, preferably iron, cobalt and nickel, stronger preferably cobalt and / or nickel, and at least one metal of Group VI, preferably molybdenum and tungsten, as well as a carrier material with big ones Surface, preferably alumina. Other suitable hydrotreating catalysts are zeolite catalysts, as well as noble metal catalysts, where the precious metal is selected from palladium and platinum. It is within the spirit of the present invention that more than a type of hydrotreating catalyst in the same reaction vessel is used. The Group VIII metal is typically in in an amount ranging from 2 to 20% by weight, preferably from 4 to 12 wt .-% present. The Group VI metal typically becomes in an amount ranging from 1 to 25% by weight, preferably from 2 to 25 wt .-% present.

The resulting effect of the denitrification and desulfurization reaction zone is transferred without intermediate heat exchange (uncooled) and into a hot stripping zone maintained under high pressure, substantially at the same pressure as the denitrification and desulfurization reaction zone where countercurrent with a hydrogen rich gas stream is stripped to produce a first gaseous hydrocarbon stream containing hydrogen, hydrogen sulfide, ammonia and hydrocarbon compounds and a second liquid hydrocarbon stream producing hydrocarbon compounds boiling at a temperature higher than 343 ° C. The stripping zone is preferably maintained at a temperature in the range of 232 ° C to 468 ° C. The outlet from the denitrification and desulphurisation zone becomes is not substantially cooled prior to stripping and would only have a lower temperature due to unavoidable heat losses during transport from the reaction zone to the stripping zone. It is preferred that carbonation of the effluent from the denitrification and desulfurization zone prior to stripping be less than 55 ° C. By maintaining the pressure of the stripping zone at substantially the same pressure as the denitrification and desulfurization zone, there is a difference in pressure due to the pressure drop required for the flow of effluent stream from the reaction zone to the stripping zone. It is preferred that the pressure drop is less than 800 kPa. The hydrogen-rich gas stream is preferably fed to the stripping zone in an amount greater than 1% by weight of the hydrocarbon feed which enters the denitrification and desulfurization zone. The hydrogen-rich gas stream used as the stripping medium in the stripping zone may first be introduced into a reflux heat exchange zone located in an upper end of the stripping zone to produce reflux therefor and then introduce the resulting heated hydrogen-rich gas stream into a lower end of the stripping zone and so on to exercise the stripper function.

At least a part of the first liquid Hydrocarbon stream containing hydrocarbon compounds which boil at a temperature in the region of the feed, which enters the denitrification and desulfurization zone, and preferably higher than 343 ° C, and from the high pressure strip zone directly into a hydrocracking zone is introduced with added hydrogen.

The hydrocracking zone may contain one or more beds of the same or different catalyst. In one embodiment, when the preferred products are middle distillates, the preferred hydrocracking catalysts employ amorphous or low-base zeolite bases and one or more Group VIII or Group VIB metal hydrogenation components. In one embodiment, when the preferred products are in the gasoline boiling range, the hydrocracking zone contains a catalyst generally comprising a crystalline zeolite cracking base on which a minor portion of a Group VIII metal hydrogenation component is deposited. Additional hydrogenation components can be selected from Group VIB for incorporation with the zeolite base. The zeolite cracking bases are sometimes referred to in the art as molecular sieves and are usually silica, alumina, and one or more exchangeable cations, such as sodium, magnesium, calcium, rare earth metals, etc. They are further characterized by relatively uniform diameter crystal pores between 4 and 14 Ångström (10 ^-10 meters). It is preferred to have zeolites with a relatively large molar ratio of silica to alumina between 3 and 12. Suitable zeolites found in nature include, for example, mordenite, stilbite, heulandite, ferrierite, Dachiardet, chabazite, erionite and faujasite. Suitable synthetic zeolites are, for example, the crystal types B, X, Y and L, for example synthetic faujasite and mordenite. Preferred zeolites are those having crystal pore diameters between 8 and 12 Angstroms (10 ^-10 meters) wherein the molar ratio of silica to alumina is 4 to 6. An excellent example of a zeolite falling within the preferred group is synthetic molecular sieve Y.

The naturally occurring zeolites are normally found in a sodium form, an alkaline earth metal form or in mixed forms. The synthetic zeolites are almost always produced in the sodium form. In any case, for use as a cracking base, it is preferred that most or all of the original zeolitic monovalent metals be ion-exchanged with a polyvalent metal and / or an ammonium salt, followed by heating to decompose the ammonium ions attached to the zeolite are at their Stel le hydrogen ions and / or exchange sites remain, which were actually dekationisiert by further removal of water. Hydrogen or "decationized" zeolites Y of this nature are more specific in the art US-A-3,130,006 B1 described.

mixed Polyvalent metal hydrogen zeolites can be obtained by ion exchange first an ammonium salt and then partial exchange with a polyvalent Metal salt and finally Calcination can be made. In some cases, as in the case of synthetic Mordenite, can the hydrogen forms by direct acid treatment of the alkali metal zeolites getting produced. The preferred cracking bases are those which at least 10% and preferably at least 20% metal cation deficiency, based on the initial one Ion-exchange capacity, to have. A specially desired and stable Class of zeolites are those in which at least 20% of the ion exchange capacity Hydrogen ions saturated are.

The metals used as hydrogenation components in the preferred hydrocracking catalysts of the present invention are those of Group VIII, ie, iron, cobalt, nickel, ruthenium, rhodium, palladium, osmium, iridium, and platinum. In addition to these metals, other promoters may also be used in conjunction therewith, including Group VIB metals, for example, molybdenum and tungsten. The amount of hydrogenating metal in the catalyst can vary widely. Generally speaking, any amount between 0.05% and 30% by weight can be used. In the case of Edel It is normally preferred for metals to use from 0.05 to 2% by weight. The preferred method of incorporating the hydrogenating metal is to contact the zeolite base material with an aqueous solution of a suitable compound of the desired metal, the metal being in a cationic form. After adding the selected hydrogenating metal (s), the resulting catalyst powder is then filtered, dried, with added lubricants, binders or the like, pelletized if desired, and calcined in air at temperatures of, for example, 371 ° C to 648 ° C to activate the catalyst and to decompose ammonium ions. Alternatively, first the zeolite component can be pelletized, whereupon the hydrogenating component is added and activated by calcination. The above catalysts may be used in neat form or the powdered zeolite catalyst may be combined with other, relatively less active catalysts, diluents or binders such as alumina, silica gel, silica-alumina cogels, activated clays and the like in proportions ranging between 5 and 90 Wt .-% mixed and pelletized together. These diluents may be used as such or may contain a minor proportion of added hydrogenating metal, such as a Group VIB and / or Group VIII metal.

Additional metal-supplemented hydrocracking catalysts may also be used in the process of the present invention and include, for example, aluminophosphate molecular sieves, crystalline chromosilicates and other crystalline silicates. Crystalline chromo-silicates are further detailed in the US-A-4,363,718 B1 described.

Hydrocracking of the hydrocarbon feed in contact with a hydrocracking catalyst is conducted in the presence of hydrogen and preferably at hydrocracking reactor conditions, which is a temperature of 232 ° C to 468 ° C, a pressure of 3448 kPa gauge to 20695 kPa, an hourly liquid space velocity ( LHSV) of 0.1 to 30 h ^-1 and a hydrogen circulation rate of 337 normal cm ³ / cm ³ to 4200 normal cm ³ / cm ³ . According to the present invention, the term "substantial conversion to lower boiling products" means the conversion of at least 5% by volume of fresh feed. In a preferred embodiment, the conversion present in the hydrocracking zone per pass is in the range of 15% to 75%. More preferably, the conversion per pass is in the range of 20% to 60%.

It is preferred that cooling the Outlet of the hydrocracking zone before stripping is less than 55 ° C. Of the Hydrocracking pressure is essentially at the same pressure as that of the stripping device.

Of the resulting first gaseous Hydrocarbon stream, the hydrocarbon compounds which boil at a temperature lower than 343 ° C, hydrogen, hydrogen sulfide and contains ammonia, from the stripping zone is preferably in a total vapor phase introduced into an aftertreatment hydrogenation zone to at least a portion hydrogenating the aromatic compounds and thus the quality of the middle distillate, in particular of the jet fuel, to improve. The aftertreatment hydrogenation zone may be in a downward direction Electricity and an upward directed stream or a radial stream and can be any use known hydrogenation catalyst. The effluent from the aftertreatment hydrogenation zone is preferably cooled down to a temperature in the range of 4.4 ° C to 60 ° C and at least partially condensed to form a second liquid hydrocarbon stream which is divided to at least part of the hydrogen-rich Gas stream, which is divided to at least part of the hydrogen-rich gaseous Generate electricity into the hot high pressure stripping device, the hydrocracking zone and the denitrification and desulphurisation zone introduced becomes. Fresh supplement hydrogen can be in the process at any convenient and convenient place be introduced. Before the hydrogen-rich gas stream split and enter the hydrocracking reaction zone introduced it is preferred that at least a significant part, such as at least 90% by weight of hydrogen sulfide and by conventional means known in the art and usual Methods is removed. In a preferred embodiment contains the introduced into the hydrocracking zone hydrogen-rich gas stream less than 50 wppm hydrogen sulfide.

detailed Description of the drawing

Referring now to the drawing, a feed stream comprising vacuum gas oil is introduced into the process via conduit 1 introduced and mixed with a liquid recycle stream, described below, via line 36 is transported. The resulting mixture is passed over line 2 transported and mixed with a hydrogen-rich gas stream via line 27 is provided, and the resulting mixture is passed over line 3 and into a denitrification and desulphurisation zone 4 introduced. The mixture passes through the denitrification and desulfurization catalyst zone 5 and optionally mixed with a liquid stream containing light cycle oil via line 6 is introduced, and the resulting mixture passes through the denitrification and desulfurization catalyst zone 7 , The resulting effluent from the denitrification and desulfurization zone 4 will be over line 8th and with an outlet from the hydrocracking zone described below 37 mixed, which latter via line 31 is conveyed, and the resulting mixture is passed over line 9 in the stripping zone 10 worn and introduced. A liquid hydrocarbon stream is flowing from the bottom of the stripping zone 10 via wire 29 removed and mixed with a hydrogen-rich gas stream passing through pipe 38 is provided, and the resulting mixture is passed over line 30 transported and into the hydrocracking zone 37 introduced. A resulting hydrocracking effluent will be from the hydrocracking zone 37 via wire 31 , as described above, removed. An optional liquid stream containing straight-run diesel is sent via pipe 12 transported and in the stripping zone 10 introduced to serve as reflux. A vapor stream is stripped and up in the stripping zone 10 carried and with the hydrogenation zone 11 contacted, and a resulting effluent is removed from the stripping zone via conduit 13 away. The resulting vapor stream coming in line 13 is included in the heat exchanger 14 introduced, and a partially condensed effluent stream is from the heat exchanger 14 removed, via wire 16 transported, brought into contact with an aqueous stream, which via line 15 is conveyed, and the resulting mixture is then passed through line 17 transported and into the high pressure separator 18 introduced. A gas stream containing hydrogen and hydrogen sulfide is removed from the high pressure separator 18 via wire 21 away and into the acid gas recovery zone 22 introduced. An impoverished solvent is sent over line 23 into the acid gas recovery zone 22 and is in contact with the hydrogen-rich gaseous stream to dissolve an acid gas. An enriched solvent containing acid gas is from the acid gas recovery zone 22 via wire 24 removed and won. A hydrogen-rich gas stream containing a reduced acid gas concentration is from the acid gas recovery zone 22 via wire 25 removed and mixed with fresh supplemental hydrogen, which via line 26 is introduced. The resulting mixture is passed over line 27 and part of it will be transported by cable 28 promoted to stripping gas in the stripping zone 10 to serve. Another part of the over line 27 transported water-rich gas stream is via line 28 transported to stripping gas in the stripping zone 10 to serve. Another part of the hydrogen-rich gas stream flowing over pipe 27 is transported via wire 38 and gets into the hydrocracking zone 37 as described above. The third and remaining part of the hydrogen-rich gaseous stream, which via line 27 is transported to the denitrification and desulphurisation zone 4 introduced as described above. A liquid stream is from the high pressure separator 18 via wire 20 removed and into the fractionation zone 32 introduced. A spent aqueous stream is removed from the high pressure separator 18 via wire 19 removed and won. Light gaseous hydrocarbons and naphtha-boiling compounds are removed from the fractionation zone 32 via wire 33 removed and won. A liquid stream containing compounds which boil in the kerosene region is removed from the fractionation zone 32 via wire 34 removed and won. A liquid hydrocarbon stream containing boiling compound in the diesel boiling range is removed from the fractionation zone 32 via wire 35 removed and won. A heavy liquid hydrocarbon stream containing compounds boiling in the region above the diesel boiling range is removed from the fractionation zone 32 via wire 36 and mixed with the fresh hydrocarbon feed as described above.

example

A feedstock in an amount of 100 mass units having the properties shown in Table 1 is introduced into a denitrification and desulfurization reaction zone along with a liquid recycle stream at the operating conditions shown in Table 2. The resulting effluent from the denitrification and desulfurization reaction zone is combined with the effluent from a hydrocracking zone and introduced into the hot high pressure stripper operating at a pressure of 1.2 MPa and a temperature of 37 ° C. A liquid hydrocarbon stream containing boiling hydrocarbons in the fresh feed region is removed from the bottom of the hot high pressure stripper and introduced into the hydrocracking zone at operating conditions designated in Table 2. Table 1 Hydrocracker feed analysis. Vacuum gas oil specific weight 0.91 Distillation, volume percent IBP ° C 222 5 356 10 396 30 429 50 448 70 475 90 502 95 517 Sulfur, percent by weight 2.22 Nitrogen, percent by weight 0.0074 (Ppm) (740) Conradson carbon, weight percent 0.15 Table 2 Summary of operating conditions Denitrification and desulfurization reaction zone Pressure, MPa 12.5 Temperature, ° C 393 Hydrocracking reaction zone Pressure, MPa 12.5 Temperature. ° C 385 Conversion per pass,% 35

The total conversion to hydrocarbons having a boiling point lower than 343 ° C is 99.5%, and a summary of the total mass balance is given in Table 3. These results demonstrate the advantages afforded by the process of the present invention when taking up a single feedstream. Table 3 Total mass balance mass units feedstocks Vacuum gas oil 100.0 hydrogen 2.8 102.8 Products hydrogen sulfide 2.4 ammonia 0.1 C ₁ -C ₄ 4.5 naphtha 23.9 distillates 71.4 Unconverted oil 0 55 102.8

Example 2

100 mass units of a feedstock having the properties shown in Table 1 are reintroduced together with a liquid recycle stream into a denitrification and desulfurization reaction zone at the operating conditions shown in Table 3. A simple FCC cycle oil in an amount of 30 mass units and having the properties shown in Table 4 is introduced at a middle point into the denitrification and desulfurization reaction zone to serve as a deterrent and to contact at least a portion of the catalyst therein. The resulting effluent from the denitrification and desulfurization reaction zone is combined with the effluent from a hydrocracking zone and introduced into the hot high pressure stripper operating at a pressure of 12.2 MPa and a temperature of 371 ° C. The hot high pressure stripper operates at reflux by introducing 20 mass units of a straight run diesel oil having the properties given in Table 4.

Table 4 Co-feed analyzes

A liquid hydrocarbon stream containing hydrocarbons boiling in the region of the vacuum gas oil feed is removed from the bottom of the hot high pressure stripper and introduced into the hydrocracking zone at the operating conditions shown in Table 3. The total conversion to hydrocarbons having a boiling range lower than 343 ° C is 99.5%, and a summary of the total mass balance is given in Table 5. Analysis of the distillate product shows that the sulfur concentration is less than 10 ppm by weight. These results demonstrate the benefits obtained with the process of the present invention. Table 5 Total mass balance mass units feedstocks Vacuum gas oil 100.0 Straight run diesel 20.0 Light cycle oil 30.0 hydrogen 3.2 153.2 Products hydrogen sulfide 3.0 ammonia 0.2 C ₁ -C ₄ 5.0 naphtha 24.0 distillate 120.5 Unconverted oil 0.5 153.2

Summary

• (a) eine kohlenwasserstoffhaltige Beschickung und Wasserstoff zu einer Denitrifikations- und Entschwefelungs-Reaktionszone mit einem Katalysator führt und einen Auslauf aus der Denitrifikations- und Entschwefelungs-Reaktionszone gewinnt,
• (b) den Auslauf der Denitrifikations- und Entschwefelungs-Reaktionszone direkt zu einer heißen Hochdruck-Strippeinrichtung überführt, die ein heißes wasserstoffreiches Strippgas benutzt, um einen ersten flüssigen Strom und einen ersten Dampfstrom zu erzeugen,
• (c) wenigstens einen Teil des ersten flüssigen Stroms zu einer Hydrocrackzone überführt und daraus einen Hydrocrackzonenauslauf gewinnt,
• (d) den Auslauf der Hydrocrackzone direkt zu der heißen Hochdruck-Strippeinrichtung überführt,
• (e) wenigstens einen Teil des ersten Dampfstroms in Stufe (b) und wenigstens einen Teil des Hydrocrackzonenauslaufs zu einer Nachbehandlungshydrier-Reaktionszone führt, um aromatische Verbindungen zu sättigen,
• (f) wenigstens einen Teil des resultierenden Auslaufs aus der Nachbehandlungshydrier-Reaktionszone kondensiert, um einen zweiten flüssigen Strom und einen zweiten Dampfstrom zu erzeugen,
• (g) wenigstens einen ersten Teil des zweiten Dampfsstroms zu der Hydrocrackzone führt,
• (h) wenigstens einen zweiten Teil des zweiten Dampfstroms zu der Denitrifikations- und Entschwefelungs-Reaktionszone überführt,
• (i) wenigstens einen dritten Teil des zweiten Dampfstroms zu der heißen Hochdruck-Strippeinrichtung überführt und
• (j) die Kohlenwasserstoffverbindungen, die bei einer Temperatur unterhalb des Siedebereichs der Kohlenwasserstoffbeschickung sieden, gewinnt.

The present invention relates to a process for hydrocracking a hydrocarbonaceous feed, comprising:

• (a) passing a hydrocarbonaceous feed and hydrogen to a denitrification and desulfurization reaction zone with a catalyst and recovering an effluent from the denitrification and desulfurization reaction zone,
• (b) transferring the effluent of the denitrification and desulfurization reaction zone directly to a hot high pressure stripping device using a hot hydrogen rich stripping gas to produce a first liquid stream and a first vapor stream,
• (c) transferring at least a portion of the first liquid stream to a hydrocracking zone and obtaining a hydrocracking zone effluent therefrom,
• (d) transferring the effluent of the hydrocracking zone directly to the hot high pressure stripping device,
• (e) passing at least a portion of the first vapor stream in step (b) and at least a portion of the hydrocracking zone effluent to an aftertreatment hydrogenation reaction zone to saturate aromatic compounds,
• (f) condensing at least a portion of the resulting effluent from the post-treatment hydrogenation reaction zone to produce a second liquid stream and a second vapor stream,
• (g) delivering at least a first portion of the second vapor stream to the hydrocracking zone,
• (h) transferring at least a second portion of the second vapor stream to the denitrification and desulfurization reaction zone,
• (i) transferring at least a third portion of the second vapor stream to the hot high pressure stripper and
• (j) the hydrocarbon compounds boiling at a temperature below the boiling range of the hydrocarbon feed win.

Claims (10)

A method of hydrocracking a hydrocarbonaceous feed which comprises: (a) a hydrocarbonaceous feed and hydrogen to a denitrification and desulfurization reaction zone at reaction zone conditions including a temperature of 204 ° C to 482 ° C, a pressure of 3.5 MPa to 17 , 3 MPa, an hourly liquid space velocity of the hydrocarbonaceous feed of 0.1 h ^-1 to 10 h ^-1 with a catalyst and an effluent from the denitrification and desulfurization reaction zone wins, (b) the outlet of the denitrification and desulfurization Reaction zone transferred directly to a hot high pressure stripping device using a hot hydrogen-rich stripping gas to produce a first liquid stream, the hydrocarbon compounds boiling in the region of the hydrocarbonaceous feed, and a first vapor stream, the hydrogen, hydrogen sulfide, ammonia and hydrocarbon (c) at least a portion of the first liquid stream comprising hydrocarbon compounds boiling in the region of the hydrocarbonaceous feed is transferred to a hydrocracking zone containing a hydrocracking catalyst and at a temperature of from 204 ° C to 482 ° C ° C, operating at a pressure of 3.5 MPa to 17.3 MPa, an hourly liquid space velocity of 0.1 h ^-1 to 15 h ^-1 and obtaining a hydrocracking zone effluent therefrom, (d) the outlet of the hydrocracking zone directly to the hot high pressure (E) passing at least a portion of the first vapor stream in step (b) and at least a portion of the hydrocracking zone effluent to an aftertreatment hydrogenation reaction zone to saturate aromatic compounds, (f) at least a portion of the resulting effluent from the post-treatment hydrogenation zone; Reaction zone condenses to form a second liquid stream, the Kohlenwasserstoffverbindunge n which boil at a temperature below the boiling range of the hydrocarbonaceous feed and to produce a second vapor stream comprising hydrogen and hydrogen sulfide, (g) at least a first portion of the second vapor stream to the hydrocracking zone, (h) at least a second (I) transferring at least a third portion of the second vapor stream to the hot high pressure stripper and (j) recovering the hydrocarbon compounds boiling at a temperature below the boiling range of the hydrocarbon feed , The method of claim 1, wherein the hydrocarbon-containing Feed into the denitrification and desulfurization reaction zone enters, a first feed and a second feed, the one hydrocarbon-containing feed stream with a lower average boiling point than that of the first feed has, in an upper end of the hot High-pressure stripping device is transferred, to serve as reflux. Process according to claim 1, in which the denitrification and desulfurization reaction zone entering hydrocarbonaceous feed is a first feed and a second feed containing a hydrocarbon Feed stream with a lower average boiling point than that of the first feed comprises, at a middle point into the denitrification and desulfurization reaction zone to serve as a deterrent. Method according to one of claims 1 to 3, wherein the second Steam stream comprising hydrogen and hydrogen sulfide treated is used to remove at least a portion of the hydrogen sulphide, and the resulting hydrogen-rich gaseous stream is less than 5 ppm by weight Contains hydrogen sulfide. Method according to one of claims 1 to 4, wherein the in the denitrification and desulfurization reaction zone in stage (a) incoming hydrocarbonaceous feed in the range from 232 ° C up to 565 ° C boils. Method according to one of claims 1 to 5, wherein the hot high pressure stripping device operates at a temperature and pressure which substantially equal to those of the combined effluent from the hydrocracking zone and the denitrification and desulfurization reaction zone corresponds. Method according to one of claims 1 to 6, wherein the hot high pressure stripping device at a temperature within the range of 55 ° C of the combined outlet the hydrocracking zone and the denitrification and desulfurization reaction zone and at a pressure within 800 kPa of the combined outlet pressure the hydrocracking zone and the denitrification and desulphurisation zone is working. Method according to one of claims 1 to 7, wherein the hydrocracking zone at a conversion per pass in the range of 15% to 75% and more, preferably in the range of 20% to 60% works. Method according to one of claims 1 to 8, in which the denitrification and desulfurization reaction zone containing catalyst Nickel and molybdenum having. A process according to any one of claims 1 to 9, wherein the post-treatment hydrogenation zone at reaction zone conditions including a temperature of 204 ° C to 482 ° C and a pressure of 3.5 MPa to 17.3 MPa works.