DE2215665A1 - INTEGRATED PROCESS OF HYDROGEN TREATMENT AND CATALYTIC CLEAVAGE FOR THE PURPOSE OF REFINING SULFURY CRUDE OILS - Google Patents

Description

PATENT ADVERTISER D-1 BERLIN 33 March 15, 1972

κ λ λ κ ir-oi-ΓΛ iiiri ir F.ALKENUIED4

MANFRED MIEHE τ * «™,« miτ * »»

Graduate chemist ¹

Docket 700007-A-WGY US / 07/1191

MARATHON OIL COM PA NY 539 South Main Street, Findlay Ohio 45840, USA

Integrated process of hydrotreatment and catalytic Cleavage for the purpose of refining sulfur-containing crude oils

Desalinated crude oil plus a recycled product stream from the catalytic cracking unit, e.g. catalytic gas oil - heavy catalytic process oil - with or without further catalytic fission products, E.g. gasoline and light process oil mixed together and in a single process step with Treated with hydrogen and then fractionated into the desired fractions. Optionally, parts of the products coming from the hydrogenation device are reformed and / or coked with liquid fractions from the coking device, which are optionally included in the process are recycled in association with the crude oil feed fed to the hydrogenator will.

The subject matter of the invention is generally in the field of hydrocarbon conversion processes, and in particular that of Hydrotreatment or hydrogenation and catalytic cracking.

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In the prior art it has become known to separate a To carry out hydrogen treatment or hydrogenation of catalytic fission product streams, see e.g. the publication by R.A. Flinn and O.A. Larson, "The Effects of Hydrogenation and Catalytic Cracking of Various Molecular Types and Middle Distillates ", J. Appl. Chem. 11, July 1961, Pages 271-276 and the publication by M.D. Abbott, R.C. Archibald and R.W. Dorn, "Hydrogen Improves Catalytic Cracker Feed ", Petroleum Refiner, 37, 161-166, 1958.

The hydrotreatment or hydrogenation of residual petroleum products is described in the following publications. NL-PS 6916 218-Q, in which a US priority dated October 28, 1968 according to the file number SN 771 248 is claimed. Here are methods of converting sulfur-containing to carbon-containing ones Black oils described as low-boiling, normally liquid hydrocarbon products with reduced sulfur content, wherein an integrated process is used in which a cracking in the presence of hydrogen and a catalytic Desulfurization takes place in a stationary bed. NL-PS 6916 017-Q, in which a US priority of October 25, 1968 according to the file number SN 770 724 is claimed, teaches the hydrodesulfurization of crude oil or reduced crude oil, the Contains asphalt fractions, at low temperatures in the presence of a metal catalyst of groups VI / VII des Periodic table arranged on alumina.

The hydrotreatment or hydrogenation of total crude oil is described in detail in a recent paper by S.G. Paradis, G.D. Gould, D.A. Bea and E.M. Reed with the Name "Isomax Desulfurization of Residium and Whole Crude Oil", which was given as lecture 31c on the occasion of Meeting of the American Institute of Chemical Engineers on February 28 - March 4, 1971 in Houston. U.S. Patent 3,562,800 deals with hydrodesulfurization of crude oil or reduced oil without recirculation of liquid products from others Units in mixing with the incoming crude oil feed.

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According to the present invention, whole crude oil undergoes hydrotreatment or hydrogenation, then fractionated and a gas oil fraction is catalytically cleaved to form liquid products. At least a portion of the liquid products then become the crude oil feed prior to the hydrogenation step supplied again or returned to the process at this point. The advantages achieved according to the invention include: Savings in capital investment by reducing the number of fractionation columns and the number required Hydrogenation units; Reduce the amount of coke - where applicable - and increase the amount of more valuable coke accordingly liquid products; low sulfur content in the liquid products and in any coke formed from the residual fractions; reduced corrosion due to sulfur removal before contact with the crude oil tower, catalytic cracking device, Coking device and the subsequent processing units; high throughput throughout the device for hydrogen treatment or hydrogenation device; the light fractions are in a hydrotreating unit or subjected to hydrogenation no greater than that for conventional hydrogen treatment or hydrogenation only the heavier fractions are required; and optionally lower olefin levels in naphtha products, especially gasoline, in those embodiments where catalytic or coke naphtha is recycled into the process.

According to the invention, gasolines are produced and optionally Reformed gasoline with improved octane number and / or coke can be obtained. These products find useful application as Fuels for engines, such fuels with improved properties or as carbon for the production of Electrodes.

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An embodiment of the invention is shown in the drawing and is described in more detail below. Show it:

Fig. 1 is a schematic drawing of the invention in

Application of the upcoming refining system for the hydrogen treatment or hydrogenation of crude oil and the catalytic! Columns;

2 shows a refining plant which additionally carries out reforming with the formation of gasoline with a higher octane number (reformate) and formation of hydrogen / which can optionally be fed again to the device for the hydrogen treatment or to the hydrogenation device ;

Figure 3 is a refining plant in which a hydrotreating or hydrogenation and catalytic cracking - is carried out, however, Lich zusätz a residual fraction under forming Verkokerflüssigkeiten coked, which can optionally be recycled into the method of mixing with the - as shown in FIG. 1 Charge for the hydrogen treatment device or hydrogenation device.

Starting products

Hydrocarbons: It is an important aspect of the invention that whole crude oil is subjected to hydrogen treatment or hydrogenation. The method according to the prior art have considered a hydrotreating and hydrogenation of residual products into consideration, that is, components having a boiling point of, for example 35O ° C and above, without that it was possible to achieve the advantages according to the invention here achieved. The crude oils which are particularly useful according to the invention include those which have a relatively high sulfur content but a low content of asphaltenic products and heavy metals. A good example of this type of crude oil is sulphurous

? 09RP3 / 0983

West Texas crude oil.

Instead of all the crude oil, slightly distilled crude oils can also be used, e.g. those in which the under about 200 ° C boiling portion has been fractionated out.

The one to be fed to the catalytic cleavage unit according to the invention The preferred gas oil fraction is preferably that proportion of the mixed distillation products and an atmospheric one as well as a vacuum distillation which remains after removing the gasoline and the light distillates and is preferably within a range of about 260-620 ° C, more preferably boiling from about 290 to 59O ° C, and most preferably from about 320 to about 56O ° C.

Residual fraction; The preferred residual fraction for the coking according to the invention is that fraction which generally boils above about 480 ° C., more preferably above about 54O ° C. and particularly preferably above about 56O ° C.

Catalytic cleavage unit liquid products; A catalytic cracking unit leads to a liquid product that is conventionally fractionated into a variety of products including catalytic gasoline, catalytic cracking agent distillate, catalytic cracking gas oil and an entrained catalyst containing slurry, with all or some of the catalysts being separated and returned to the catalytic cracking unit will.

Catalytic cracked gas oil; In many conventional operations, gasoline is obtained as the end product, with the middle distillate and / or the catalytic process oil being returned to the catalytic cracking unit. According to the invention, the catalytic cracked gas oil - and optionally the middle distillate and / or gasoline - is used for mixing with the crude oil feed

209883/0983

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for the hydrogen treatment device or the hydrogenation device applied. The cracked catalytic gas oil is generally more preferred in a range of about 230 to about 510 ° C about 260 to about 500 ° C and particularly preferably about 320 to about 480 ° C.

Coker liquid products; The liquid products of the coking device selected for return to the process will generally consist of the entire liquid product with C ₅ or Cg hydrocarbons up to the highest-boiling liquid products formed. The low molecular weight product, in particular the C ₃ , C ₄ and possibly Cc fractions, are advantageously separated off for the recovery of olefins. All other portions of the liquid product of the coking device can, if necessary, also be separated off for separate use. About 1 to about 100 percent by volume, more preferably about 50 to about 100 percent by volume, and particularly preferably 75 to about 100 percent by volume of the liquid products (with C ₃ and higher hydrocarbons) coming from the coking device are mixed with the total crude oil that is in the Hydrogenation process occurs. To the extent that coking liquids remain, they can be used for conventional purposes such as gasoline and heavy fuels.

Hydrogen; The hydrogen used according to the invention can have a commercially available degree of purity, as it is obtained by reforming naphtha, for example by means of the reforming processes, as described on pages 184-193 of the September 1970 issue of the publication "Hydrocarbon Processing", or the hydrogen can be used specifically for this purpose can be produced in that steam is reformed or a partial oxidation of hydrocarbons takes place - see the same publication on pages 269-270 -. There are about 240 m to about 1440 m, more preferably about 480 m to about 1190 m and especially preferred

209883/098 3

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3 3

about 600 m to about 950 m of hydrogen in use, each with an amount of oil per m of oil for the Hydrogenation device are brought into contact.

Catalyst for hydrogen treatment or hydrogenation;

A wide variety of different hydrogenation catalysts can be used are used, and these include in particular those metals from the group consisting of nickel, molybdenum and cobalt and tungsten, or compounds containing such metals. These include those catalysts that are used by by the Girdler Division of Chemetron Corporation under the trademarks "Girdler G-51" and "Girdler G-76" to be brought; those catalysts sold by the Union Oii Company of California under the trade designation "N-21" be placed on the market; those catalysts sold by the American Cyanamid Company under the trademark "Cyanamid HDS-2A" and "Cyanamid HDS-1450", Cyanamid HDS 1441 ", "Cyanamid HDS-9A" and Cyanamid HDS-3A "are those catalysts sold by Davison Chemical Company Division of the W.R. Grace & Co. under the trade designation "Davison-HDS"; those Catalysts sold by the Nalco Chemical Company under the ' Trade name "Nalco NM-502" will be placed on the market; those catalysts made by the Catalyst and Chemicals Inc. under the trade designation "CCI C-20-07". These are nickel-molybdenum catalysts, e.g. those from American Cyanamid under the designation HDS-3A, HDS-9A and Nalco NM-502 the preferred catalysts.

Carriers for the hydrogen treatment or hydrogenation catalysts: The preferred catalyst carriers are alumina, silica, magnesium oxide or combinations thereof.

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ten action conditions occurs. For use in a stationary bed hydrogenation unit becomes a catalyst in the form of an extrudate, pellet or bead of such Size used to avoid excessive pressure drop through the catalyst bed, but the size is sufficient is small in order to enable good transport of the oil to the center of the catalyst particle being used. Sizes of about 3.2-1.6 mm are generally preferred. On one working with moving or boiling bed Hydrogenation reactors, extrudates or other shaped particles with a dimension of 0.8 mm or smaller are advantageous.

Hydrogenation temperature ; While the temperature during the hydrotreatment or hydrogenation reaction is not particularly critical, it should range from about 320 to about 450 ° C, more preferably from 350 to about 430 ° C, and most preferably from about 360 to about 415 ° C . The temperature employed will depend on the relative hydrodesulfurization and hydrocracking activities of the particular catalyst in use and will normally increase during throughput to compensate for deactivation of the catalyst.

Hydrogenation pressure: Even if the pressure during the hydrogenation reaction is not critical in the strict sense, it should be

the same but to about 17.5 to about 350 kg / cm, stronger

preferably to 42 to about 175 kg / cm and particularly preferred

2
amount to about 56 to about 140 kg / cm.

Hourly space velocity of the liquid during hydrogenation; This rate will generally range from about 0.5 to about 6, more preferably from 0.5 to about 4, and most preferably from about 1 to about 3 volumes of liquid per volume of hydrogenation catalyst per hour .

Catalytic cleavage ; The catalytic cracking is carried out under conventional conditions such as those described on pages 174-179 of the September 1970 issue

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2215685

from Hydrocarbon Processing and in the litera = sucked in there are described. The catalytic cracking catalysts are generally mixtures of silica and alumina cAsr. Magnesium oxide and preferably contain crystalline compounds of silica and alumina, commonly known as "Zeolites" or "Molecular Sieves" are known,

Suitable catalytic cracking catalysts are described in Hydrocarbon Processing Volume 47, No. 2, pages 125-132 (February 1968).

Verokoken; The coking is carried out under conventional conditions, for example as described on pages 180-181 of Septemberaus'ja.be 1370 of Hydrocarbon-Processing and the references cited therein.

Device ; Conventional apparatus for hydrogenation, distillation, catalytic cracking, reforming and coking can be used. Although this is not necessary for the subject matter of the invention, when using crude oil with a high content of metals and / or particulate products, a conventional protective housing filled with cheap catalyst can be placed upstream of the main hydrogenation reactor in order to protect the more expensive main catalyst .

The invention is further elucidated in the following by way of example with the aid of a number of exemplary embodiments. Examples 1 and 3 correspond to the subject matter of the invention. Examples 2 and 4 are comparative examples which illustrate the loss of the advantages of the invention in the event that the crude oil and recycled into the process stream are not hydrogenated. Example 5 illustrates the use of the naphtha product as a feed to the reformer.

_ 9. 209883/0983

example 1

Hydrogen treatment'or hydrogenation of the total crude oil and catalytic cleavage in the manner according to the invention.

Referring to Figure 1, the total crude oil 10 enters the desalination apparatus 11 of conventional design in which inorganic halides are removed. The desalinated crude oil is heated in the heat exchanger 12, brought into contact with additional hydrogen 14 and hydrogen 2 3 which is returned to the process. There is then still another heating in the furnace 13. The stream of hot crude oil and hydrogen is over a catalyst bed of nickel-molybdenum catalyst, known by American Cyanamid

HDS-3A is sold in the hydrogenator 15 at 370 ° C,

2
a pressure of 105 kg / cm and a space velocity of

- 1 3 3

1.64 h and a hydrogen-oil ratio of 800 m / m. The hydrotreated or hydrogenated stream is cooled in the heat exchanger 16 and fed to a separator 17 which separates the gaseous from the liquid products. The gaseous products from the separator 17 are washed with removal of hydrogen sulfide and ammonia from the hydrogen stream 33 to be recycled to the process. A small stream 34 is removed to avoid a build-up of C ₁ to C 3 hydrocarbons in the recirculated stream. The liquid products coming from the separating device 17 are fed to the main distillation columns 18, where they are fractionated into product streams, namely gas 19 - consisting essentially of C. to C.sub.1 hydrocarbons, which are fed to a conventional system for gas concentration from gasoline 20 - the same consists essentially of C ₅ to C - fractions that boil up to about 200 ° C and is fed to a mixing plant and / or catalytic reforming -, a middle distillate 21 - which can be more than one fraction and essentially consists of Kerosene, diesel fuel and jet fuel consists - a gas oil 23 - which consists of both

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atmospheric as well as vacuum gas oil - the catalytic cleavage device 43 is fed and-off Residual products 22, which can optionally be subjected to conventional coking? = device are supplied to produce coke.

The catalytic cleavage unit 43 is pre-heated at a temperature. 485 ° C, a space velocity on a weight basis VOL x 2.14 h and a catalyst / oil ratio (on a weight basis) of 5.6 using a catalyst sold by American Cyanamid under the designation TS = -170 in the Trade is brought.

The product coming from the catalytic cleavage device 43 is fractionated in the fractionation column 27. The top distillate 28 from the column 27 is partially condensed with separation in the separating device 40 into a Gbendestillac 30, consisting essentially of C. and lighter hydrocarbons, which are fed to the gas concentration, and a lower distillate stream 46, which consists essentially of hydrocarbons from Cc hydrocarbons and above with β ± ϊκ -: \ Boiling range of 200 ⁰ C, and this product is added to the admixture with gasoline or can optionally be mixed with the crude oil flow that comes from the desalination device 11 for the purpose of returning to the Eydris purity Γ, The fraction 44 from the fractionation column 27 consists essentially of hydrocarbons, the boiling range of which is around 200 to 320 ° C. and is used for mixing with diesel fuel, heating oil, kerosene and turbine fuel, or the product can optionally be mixed with that from the Desalination device 11 coming crude oil stream are mixed purpose s return to the hydrogenation device 15 =

4 5 The fraction / coming from the fractionation tower 27 consists essentially of hydrocarbons with a boiling range of 320 to 450 ° C. and is returned to the process for the purpose of mixing with that emerging from the desalination device 11 Product. The coming from the fractionation column 27

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Restfraktiou is cooled in the heat exchanger 49, and Entrained catalyst is optionally separated in sludge separator 47 for recycling catalytic cleavage unit 43 in the form of stream 29.

The crude oil 10 used according to Examples 1 to 4 is a sulfur-containing crude oil from West Texas and contains 1.67 wt% sulfur. The sulfur contents of the various distillation fractions of the crude oil are shown below .

Table I.

crude oil

Volume percent Gev

sulfur

Distillation fraction ⁰ C percent by volume percent by weight

below 200 18.96 0.16

200-320 _m 22.13 0.63

320-560 38.00 1.65

560 plus 20.91 2.62

Those after the hydrogen treatment or hydrogenation and fractionation The liquid products obtained have the composition shown below.

Table II

hydrotreated or hydrogenated products

.c \ sulfur

Distillation fraction C percent by volume percent by weight

below 200 18.66 <0.01

200-320 24.38 <0.01

320-560 41.64 0.12

560 plus 15.32 0.74

The process according to the invention thus leads to a substantial reduction in the sulfur content of all liquid products including the gas oil 23, which is then used as a feed product for the catalytic cracking unit

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To show the improved yields that result of the splitting of the gas oil, which is based on the hydrogen treated or hydrogenated mixture of the gas oil from the catalytic cleavage unit and the complete crude oil - compared to the gas oil obtained from the crude oil and the gas oil of the catalytic cracking unit, as in the example 2 describes mixtures that contain the same amount (vol.%) Gas oil of the catalytic cleavage unit contained in crude oil, split. They do not always reflect balanced gas oil flows, since there is less gas oil starting from the with Hydrotreated or hydrogenated feed - under equivalent cracking conditions - is formed. The yields are shown in the following table as a percentage by volume of the load, unless otherwise noted.

dry gas (m / m) propane propylene isobutane η-butane butylene C ₅ - 200 ° C

200-320 ° C 32O ° C plus coke (wt.%)

Table III example
2 example
3 example
4: example
1 30.4 27.0 30.7 26.4 2.5 2.4 2.5 2.4 7.0 7.1 7.5 7.2 4.6 5.8 5.2 5.6 1.2 - 1.4 1.3 1/2 6.8 6.8 7.9 6.4 50.8 63.1 56.3 " 59.4 18, 7 14.7 17.2 16.1 17.3 8.5 12.7 11.5 5.8 4.75 5.57 4.75

The catalytic cleavage tests in connection with the subject of the invention are carried out in small, stationary bed laboratory reaction devices. The yields are converted using unit factors defined as the yield in one refinery unit / yield in the laboratory unit, the more closely matched the yields to correspond to the one in a catalytic cleavage unit Fluidized bed refinery under balanced conditions expected at about the same temperature. In all In the examples, the same set of unit factors is used.

- 13 -.

Example 2

This is a comparative example and is used to demonstrate the Fission yields, as they result from the conventional processing of gas oil, one of which is sulfur-containing Runs out of crude oil and does not proceed according to the invention. The gas oil described in Table I of Example 1 is under the Cleavage conditions of Example 1 cleaved. The yields of cleavage products are shown in Table III. The use of 1.2 vol.% catalytic cracking gas oil in the crude oil is equivalent to a conventional catalytic cracking process, where the combined charge ratio - total charge / fresh charge is about 1.4: 1. A comparison of the yields using Examples 1 and 2 shows the markedly improved conversion and selectivity in gasoline as well as reduced coke production, as is the result of the invention.

Example 3

This example shows the advantages of the hydrogen treatment or hydrogenation of the condensate of the coking device together with crude oil in the manufacture of a feed product for catalytic cracking.

With reference to FIG. 3, crude oil 10 is processed as in FIG. 1 to obtain a residual fraction 22 which is used as feed to a conventional coking unit 60. The products obtained by means of the coking unit 60 consist of coke 64 and a superheated steam stream, which cools and then in the separating device 61 into a gaseous stream 62, which consists essentially of hydrogen and C _{1 to C 4} hydrocarbons, which is fed to a gas concentration plant for the purpose of separation and Further processing are fed, split, and a liquid stream 63, which consists essentially of Cg hydrocarbons and higher-boiling hydrocarbons up to a boiling point of about 510 ° C

09883/0983

and with the coming from the desalination device 11 Crude oil stream is mixed. The liquid product stream 63 can optionally be fractionated or divided and only one Part of this stream are mixed with the stream emerging from the desalination device 11, the remaining part for product blending and other conventional uses in the refinery.

The crude oil according to Example 1 is together with 15 percent by volume of the condensate from the VerkokuhgsVorrichtung, as it is through conventional coking at 520 ° C is obtained, along with Residual fraction from the crude oil according to Example 1, which according to the conditions according to Example 1 of a hydrogen treatment or Has been subjected to hydrogenation, a hydrogen treatment or subjected to hydrogenation and catalytic cleavage as described in Example 1. The coking unit is at a Operating temperature of 495 ° C operating temperature with a feed inlet temperature of 538 ° C. The ratio of oil to Steam loading amounts to 20.5 Volüumina oil per Volume of water. The coking time is 9 hours. The result of the catalytic cracking of the 320-525 ° C gas oil fraction yields obtained, the gas opening fraction from the hydrogenated mixture consisting of 15 percent by volume of condensate from the coking device and 85 percent by volume of crude oil, see Table III.

Example 4

This comparative example shows the lower yield of gasoline produced by conventional catalytic cracking of original and coking gas oil has been obtained with no treatment with hydrogen or hydrogenation.

A mixture of 15 volume percent coking gas oil, see Example 3 and 85 percent by volume crude oil, see Example 1, distilled to obtain a gas oil fraction having a boiling range from about 320 to about 525 ° C. This gas oil is catalyzed

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split table, see Example 3. The yields are shown in Table III. The yield of gasoline (C, - hydrocarbons, 200 ⁰ C) is significantly lower than when applying the method according to the invention in Example 3 and the amount of coke is greater, resulting in a greater loss of valuable products in the form of coke and thus a larger air volume for regenerating the catalytic converter can be displayed.

Example 5

In this embodiment, the naphtha product is reformed to form a high octane gasoline and hydrogen, which can be used in the treatment with hydrogen or hydrogenation.

With reference to FIG. 2, crude oil 10 is processed as in Example 1, this using the main column or columns 18 produced naphtha 20 is used as a feed for the catalytic ^ reforming unit 50. The reforming unit consists of a hydrogenation reactor and various reforming reactors together with the necessary furnaces and Auxiliary equipment. The product stream is cooled and then in the separating device 51 into a liquid product 52 of high octane number and split a gas stream 53 consisting predominantly of hydrogen and partly as stream 54 to the reforming reactor recycled and partly as stream 55 for use elsewhere, e.g. in the hydrogenation unit 15 is partially deducted.

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Claims (17)

Claims . > ^K V. Process for the production of gasoline starting from a gas oil obtained by the fractionation of crude oil, characterized in that the crude oil is subjected to a treatment with hydrogen or hydrogenation before the fractionation, which leads to the gas oil, the handling · treatment with hydrogen or hydrogenation is carried out in that the crude oil with about 240 to about 1440 m of hydrogen per m of crude oil at a temperature of about 320 to about 450 ° C and a pressure of about 17.5 to about 350 kg / cm is brought into contact in the presence of a hydrogenation catalyst, the gas oil fraction of the resulting hydrogenated crude oil is fractionated and catalytically cracked, and at least a portion of the liquid products from the catalytic cracking device is returned to the process while mixing with the crude oil before treatment with hydrogen or .. of hydrogenation. 2. The method according to claim 1, characterized ge ke η η ζ e ic h net that the crude oil is distilled with removal of the ^{fraction boiling below about 200 0} C, bedvör the treatment with hydrogen or hydrogenation of the crude oil is carried out. 3. The method according to claim 1, characterized geke η η ζ ei c h net that the crude oil with about 480 to about 1190 m water. substance per m 2 of crude oil is brought into contact at a temperature of about 350 to about 430 ° C. and under a pressure of about 42 to about 175 kg / cm .; 4. The method according to claim 1, characterized in that liquid products of the catalytic cleavage device which contain gasoline, as well as at least part of it is returned to the proceedings for one Mixing with the crude oil supplied by the hydrogenation device and at least a portion of the product emerging from the hydrogenation device is reformed to form a - 2 0 9883/0903 - 18 high octane gasoline. 5. The method according to claim 1, characterized in that the hydrogenated products coming from the hydrogenation device are fractionated to form a residual product ; and at least a portion of the residual product is coked with the formation of coke and liquid products. 6. The method according to claim 5, characterized in that that at least a portion of the liquid products from the coking device is returned to the process for mixing with the crude oil fed to the hydrogenator. 7. The method according to claim 1, characterized in that a metal on the hydrogenation catalyst Group nickel, molybdenum, cobalt and tungsten or a compound containing these metals is used. 8. The method according to claim 4, characterized in that that the crude oil with about 480 to about 1190 m of hydrogen per m of crude oil at a temperature of about 350 to about 430 ° C and under a pressure of about 42 to about 175 kg / cm is brought into contact. 9. The method according to claim 5, characterized in that the crude oil is distilled with removal of the about 200 C boiling fraction before the treatment with hydrogen or hydrogenation of the crude oil is carried out. 10. The method according to claim 1, characterized in that the liquid products of the catalytic cleavage device represent those which contain gas oil and at least a portion thereof is returned to the process for mixing with the crude oil fed to the hydrogenator. - 18 - 209RR3 / 0983 11 .. The method according to claim 1, characterized in that that liquid products of the catalytic cracking device are used, which are both a gas oil and a middle distillate contained, and at least a portion of the gas oil and the middle distilate is returned to the process crude oil fed to the hydrogenation device for mixing. 12. Process for the production of gasoline and refined, liquid hydrocarbons by means of cracking in a catalytic cracking device, whereby a gas oil fraction is obtained is starting from a total crude oil or a crude oil that has been distilled, removing a fraction that boiling below 200 C characterized by the Combination of the following process steps: a) Desalination of the crude oil, if necessary with reduction the content of inorganic halides, b) bringing the crude oil into contact with at least one portion of the liquid products from the catalytic cracking device 3 3 tang and with about 480 to about 1190 m hydrogen per m Oil to form a hydrocarbon and hydrogen stream, c) Passing the hydrocarbon and hydrogen stream over a hydrogenation catalyst at a temperature of about 360 to about 415 ° C and under a pressure of about 56 to 2
about 140 kg / cm and a liquid space velocity of about 0.5 to about 4 volumes of liquid per volume of the hydrogenation catalyst per hour to form a hydrogenated product stream, d) fractionating the hydrogenated product stream to form a plurality of refined liquid hydrocarbon products and a tail stream, e) splitting in a catalytic splitting unit of the gas oil fraction with a boiling range of about 320 to about 59O C, as obtained from the fractionation stage, - 19 - 7-9-83 / 0983 f) Coking at least a portion of the residual flow in a conventional coking device with formation of coke and a top distillate, g) fractionating the top distillate from the coker to form a lower boiling one Fraction with C. hydrocarbons and lighter ones Hydrocarbons and at least one high-boiling stream with (^ -hydrocarbons and heavier hydrocarbons. 13. The method according to claim 12, characterized e t that at least a portion of the higher-boiling fraction from the fractionation of the top distillate of the coking device is returned to the process for mixing with the crude oil or distilled crude oil supplied to the hydrogenation device is fed. 14. Method of making gasoline and refined liquid Hydrocarbons starting from a total crude oil or crude oil that has been distilled while removing one under The fraction boiling at around 200 ° C, characterized by the combination of the following process steps: a) Desalination of the crude oil, if necessary with reduction the content of inorganic halides, b) bringing the crude oil into contact with at least a portion of the liquid products from the catalytic cracking device and with about 240 to about 1190 m of hydrogen per m of oil to form a hydrocarbon and hydrogen stream, c) passing the hydrocarbon and hydrogen stream over a hydrogenation catalyst at a temperature of about 360 to about 415 ° C and under a pressure of about 56 to about 140 kg / cm and a liquid space velocity from about 0.5 to about 4 volumes of liquid per volume of hydrogenation catalyst per hour to form a hydrogenated product stream, - 20 - 2 0 9883/0983 ■ - 21 - d) fractionating the hydrogenated product stream to form a plurality of refined liquid hydrocarbon products and a residual current, e) reforming at least a portion of the refined liquids Hydrocarbon products in a reformer to form gasoline with improved gasoline number and Hydrogen, " f) splitting in a catalytic splitting unit of the gas oil fraction a with a boiling range of about 320 to about 590 C, such as obtained based on the fractionation stage, 15. The method according to claim 14, characterized in that that at least a portion of the hydrogen in the process is returned to the hydrogenation device. 16. The method according to claim 14, characterized e t that the hydrogenated product stream is fractionated to form a plurality of refined liquid hydrocarbons products with one. Residual current, as well as at least a portion the residual flow is coked in a coking device to form coke and a top distillate from the coking device, this top distillate from the coking device is fractionated to form a top distillate with (^ -hydrocarbons and lighter hydrocarbons and at least one high-boiling stream with Cc hydrocarbons and heavier hydrocarbons. 17. The method according to claim 14, characterized in that at least a portion of the higher boiling Fraction as it has been preserved from the coking device on the basis of the fractionation of the top distillate, is returned to the process for mixing with the crude oil or distilled crude oil supplied to the hydrogenation device is fed. - 21 - 2098-83 / 0983 Blank page