DE2215665B2 - Process for producing gasoline and refined liquid hydrocarbons - Google Patents

Description

3 4

a plurality of different hydrocarbon splitting - as in FIG. 1 shown - performed

Substance products is optional and therefore dependent, but also a residual fraction under

of the circumstances. formation of coking liquids coked, the optional

The method according to the invention can now be wisely returned to the method

characterized that the oil of a hydrogenation under 5 under venniches with the feed for the water

Use of 240 to 1440 m ^{s of} hydrogen per m ^{3 of} material treatment device or hydrogenation pre-

oil at a temperature of 350 to A jö ^c C and one direction.

Pressure from 17.5 to 350 kg / cm * in the presence of a starting product
Hydrogenation catalyst before fractionation

thrown in the subsequent Fraktionieiung io hydrocarbons: the total *; Crude oil is subjected to the resulting gas oil fraction of the hydrogenated oil catalytically hydrogen treatment or hydrogenation, split, and at least a portion of the liquid hydrogen treatment or hydrogenation of residual products coming from the prior art method is returned to the process under a catalytic splitting device products considered, ie proportions with mixing with the starting oil before performing 15 a boiling point of z. B. 35O ⁰ C and above, without the hydrogenation. that it was possible that achieved here according to the invention

Since it is therefore possible according to the invention to achieve the advantages. According to the invention,

whole crude oil, or a crude oil from which only the purposeful crude oils belong to those who

relatively volatile components have been removed, relatively high sulfur contents, but lower contents

subject to hydrogenation before any asphaltene products and heavy metals

and have other refining operations, such as a sulfur-containing crude from West Texas,

winning a variety of products, all of which instead of all of the crude oil can also be easily

are hydrogenated, there is a substantial reduction in the use of distilled crude oils, e.g. B. those

with regard to the outlay in terms of equipment in which the portion boiling below approx. 200 ° C

Compared to the state of the art, since no fractionation whatsoever has been carried out.

separate hydrogenation plants are necessary. According to the invention, there is also a reduction in the preferred gas oil fraction to be supplied to the unit, the amount of coke, where applicable, and corresponding preferably that proportion of the mixed distillation increase in the amounts of more valuable liquid prolation products, both atmospheric and ductile; low sulfur content in the liquid products, including from vacuum distillation, which remains after removal of products and in each of the gasoline and light distillates formed from the residual fractions, and coke; Reduced corrosion caused by the is preferably within a range of 260 sulfur removal before coming into contact with the up to 620 ^c C, preferably from 290 to 59O ⁰ C and especially crude oil tower, catalytic cracking device, special boil from 320 to 560 ^c C,
processing device and the subsequent processing 35 Soil fraction: The preferred soil fraction for processing units; Durchsau high throughout the coking of the invention is that frac tion device for hydrotreating or hydrogenation, generally above about 480 ^C C., preferably above device; the light fractions are boiling at a temperature of about 54O ⁰ C and in particular above about 560 ° C. Hydrogen treatment or hydrogenation unit Liquid products of the catalytic cleavage unit: subjected to no greater than that required for the conventional hydrotreatment or hydrogenation product, which is conventionally required in a large number of only the heavier fractions ; Products is fractionated, including catalytic and optionally lower olefin contents in heavy see gasoline, catalytic cracking agent distillates, gasoline products, especially gasoline, in those catalytic cracked gas oil and an entrained Kata embodiments, where catalytic or coke-containing slurry, where the scliwerbenzin in the method is Retired ührt ^f. All or part of the catalysts removed

According to the invention, gasolines are produced, and it separates and returns to the catalytic cleavage unit.

can optionally be reformed gasoline with improved runs.

Octane number and / or coke can be obtained. This catalytic fission gas: with many conventional ones

Products are used as fuels for so operations, gasoline is obtained as the end product,

Engines, fuels of this type with improved self- being the middle distillate and / or the catalytic

shafts or carbon for the production of elec-

trodden. to be led. According to the invention, the catalytic

An embodiment of the invention is in the cracked gas oil - and optionally the middle distillate and / Drawing shown and is described in more detail below 55 or gasoline - for mixing with the crude oil. It shows charging for the hydrotreating device

F i g. 1 a schematic drawing of the invention or the hydrogenation device applied. That

According to the refining catalytic cracked gas oil used is generally used in a

system for the hydrotreating or hydrogenation ranging from 230 to 510'C, preferably from 260 to 500 ^{° C} C

tion of crude oil and the catalytic cracking; 60 and especially from 320 to 480C boil.

F i g. 2 a refining plant that also re-Liquid products of the coking device: The

Formations carried out under formation of gasoline selected for return to the process

with higher octane number (reformate) and formation of liquid products of the coking device

Hydrogen, which is optional of the device for generally consisting of the entire liquid product with

Hydrogen treatment or hydrogenation device _{- 65 C 5} - or Ce hydrocarbons up to the formed

can be re-fed; highest boiling liquid products exist. That

F i g. 3 a refining plant in which a water-low molecular product, in particular the C ₃ -, C ₁ -

substance treatment or hydrogenation and catalytic and possibly C ₅ -AnieHe are more advantageous-

separated wisely for olefin production. All other hydrogenation pressure: even if the pressure during the

Fractions of the liquid product of the coking hydrogenation reaction are not critical in the narrower sense

If necessary, the device can also be for one, but it should be 17.5 to 350 kg / cm ² ,

separate use. It is preferred to 42 to 175 kg / cm ² and in particular to

1 to 100 percent by volume, preferably 50 to 100 percent by volume, 56 to 140 kg / cm ^a .

percent and especially 75 to 100 percent by volume Liquid hourly space velocity of the liquid products (with C ₃ - and higher carbons - during hydrogenation: this velocity becomes hydrogen) from the coking device generally granulates to about 0.5 to about 6, preferably mend, mixed with the total crude oil entering the 0.5 to 4, and especially 1 to 3 volume, liquid hydrogenation process. To the extent that coking wedges remain per volume of hydrogenation catalyst per liquids, these can run for hours.

Convenient purposes, e.g. B. for gasoline and heavy catalytic cracking: The catalytic cracking

Fuels. is carried out under conventional conditions,

Hydrogen: The water used according to the invention z. B. those like them on pages 174 to 179 of the Hydrogen can be commercially available, September 15, 1970 issue of Hydrocarbon like that obtained through the reforming of heavy gasoline processing and in the literature referenced there will, e.g. B. are described by means of the reforming points. The catalytic cracking process, as they are on pages 184 to 193 of the September catalysts are generally mixtures of silica 1970 edition of the publication »Hydro- and alumina or magnesium oxide and contain pre-carbon "K ~ Cb & lag" are described, or the water ao preferably crystalline compounds of silica and This substance can be produced specifically for this purpose by using clay, which is commonly known as "zeolites" or "molewe", that water vapor is reformed or a kularsieb "are known.

Partial oxidation of hydrocarbons takes place - see Suitable catalytic cracking catalysts are

the same publication on pages 269/270. Written in Hydrocarbon Processing, Vol. 47, No. 2,

There are 240 to 1440 m ³ , preferably 480 to 5 p. 125 to 132 (February 1968).

1190 m * and in particular 600 to 950 m ^s hydrogen coking: The coking is carried out under conventional

in application, each performed with an amount of per conditions, e.g. B. like them on the

m ^s oil charge for the hydrogenation device in loading p. 180/181 of the September 1970 issue of Hydro-

be moved. carbon processing and the lit-

Catalyst for hydrogen treatment or the 30 temperature points are described.

Hydrogenation: L »can be a great variety of different devices: It can be a conventional device

iicher hydrogenation catalysts are used for hydrogenation, distillation, catalytic

and this particularly includes those who applied Me-splitting, reforming and coking

metals from the group of nickel, molybdenum, and cobalt. If this also applies to the subject matter of the invention

Tungsten, or a compound containing such metals, is not required, can be used when using crude oil

fertilize, contain. with a high content of metals and / or particulate

Carrier for the hydrogen treatment or the shaped products a conventional protective housing,

Catalysts used for hydrogenation: The preferred one filled with cheap catalyst, upstream

Catalyst supports are alumina, silica, magne- plus the main hydrogenation reactor,

silicon oxide or combinations thereof. In general, the more expensive main catalyst is used

think the wearer shouldn't be so pissed off that protect.

considerable hydrogen splitting of the oil under the preferred reaction conditions. For example, using a number of exemplary embodiments in a stationary bed, the following are explained: Examples 1 and 2 correspond to the hydrogenation unit being a catalyst in the form of an object of the invention. Comparative Examples 1 and 2 of extrudates, pellets or spheres of such size illustrate the loss of the advantages of the invention, that excessive pressure drop, in the event that crude oil and the catalyst bed in the process is avoided, but the size recirculated stream are not hydrogenated. The fact that it is sufficiently small to ensure good transport of the game 3 explains the use of heavy gasoline as oil in the middle of the feed for the reformer that is in use.
Allow catalyst particles. In general, “. . ..
Sizes from about 3.2 to 1.6 mm are preferred. At 0 e 1 s ρ 1 e 1 1
a moving or boiling bed hydrogen treatment or hydrogenation of the working hydrogenation reactor are extrudates or velvet crude oil and catalytic cracking in the inventively shaped particles with a dimension of 55 according to the invention.
0.8 mm or less is advantageous. With reference to FIGS. 1, the overall

Hydrogenation temperature: Even if the temperature of crude oil 10 in the desalination device 11 is conventional

during the hydrogen treatment or the hydraulic type, in which inorganic halides

reaction is not particularly critical, it should be removed. The desalinated crude oil is in the heat

the same but heated to values of 320 to 450 ° C., preferably 60 exchangers 12, with additional hydrogen 14 μm

350 to 430 ^E C and in particular 360-415 ° C recirculated in the process, hydrogen 33 it

amount to. The applied temperature brought into contact. Another follows:

is from the relative hydrodesulphurisation and heating in the furnace 13. The stream out is hot

Hydro cracking activities of the special in application crude oil and hydrogen is carried out over a catalyst bed

coming catalyst depend and is nor- 65 from nickel-molybdenum catalyst in the hydrogenation

sometimes increase during "fine throughput device 15 at 370 ° C, a pressure of 105 kg / cm

to compensate for a deactivation of the Ka and an Rsram speed of 1.64 rr ¹ un <

talysators. a Wassei-sloff-oil ratio of 800m ^a / m ³ ge

<b

leads. 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, starting from the separator device 17 are washed with removal of hydrogen sulfide and ammonia stream from the attributable to the process hydrogen 33 A small stream 34 is removed to too high a content of C ₁ - recirculated to Cs hydrocarbons in the Avoid electricity. 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 ₁ - to Ci hydrocarbons, which are fed to a conventional system for gas concentration - from gasoline 20 -, the same consists essentially of C ₅ - to C _ir fractions which boil up to about 200 ⁰ C, and is fed to a mixing plant and, or catalytic reforming, a middle distillate 21 - which can be more than one fraction and consists essentially of kerosene, diesel fuel and jet fuel -, a gas oil 23 - consisting of both atmospheric and vacuum gas oil - which is fed to the catalytic cracking device 43, and the bottoms fraction 22 which is optionally fed to a conventional coking device.

The catalytic cracking unit 43 is operated at a temperature of 485 ⁰ C, a space velocity on the weight basis of 2.14 h ¹ and a catalyst / oil ratio (weight) of 5.6 employing a catalyst.

The product coming from the catalytic cleavage device is fractionated in the fractionation column 27. The upper distillate 28 from the column 27 is partially condensed with separation in the separation device 40 into an upper distillate 30, consisting essentially of C ₄ and lighter hydrocarbons, which are fed to the gas concentration, and a lower distillate stream 46, which essentially consists of hydrocarbons and above with a boiling range up to 200 ⁰ C, and this product is mixed with gasoline or can optionally be mixed with the crude oil stream coming from the desalination device 11 for the purpose of returning to the hydrogenation unit 15. The fraction 44, starting from the fractionation column 27, consists in the essentially of hydrocarbons, whose boiling range amounts to about 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 the crude oil stream coming from the desalination device 11 for the purpose of returning to the hydrogenation device 15th The fraction 45 coming from the fractionation tower 27 consists essentially of hydrocarbons with a boiling range from 320 to 450 ^° C. and is fed back into the process for the purpose of mixing with the product emerging from the desalination device 11. The residual fraction coming from the fractionation column 27 is cooled in the heat exchanger 49, and entrained catalyst is optionally separated off in the sludge separation device 47 for the purpose of returning to the catalytic cleavage unit 43 in the form of a 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 weight percent sulfur. The sulfur content of the various distillation fractions of the crude oil are shown below.

Table I.
crude oil

¹⁰ distillation fraction
^! C. Volume percentage Weight percent
sulfur below 200
200 to 320
¹⁵ 320 to 560
560 plus 18.96
22.13
38.00
20.91 0.16
0.63
1.65
2.62

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

Table II
hydrotreated or hydrogenated products

Distillation fraction
⁰ C Volume percentage Weight percent
sulfur below 200
³⁰ 200 to 320
320 to 560
560 plus 18.66
24.38
41.64
15.32 <0.01
<0.01
0.12
0.74

The process according to the invention thus leads to a substantial reduction in the sulfur content all liquid products including gas oil 23 which is subsequently used as feed product for the catalytic cleavage unit is applied. To show the improved yields that can result * ° Reason of splitting gas oil resulting on hand the hydrogenated or hydrogenated mixture of the gas oil from the catalytic cracking unit and the whole crude oil has been obtained - compared to the gas oil obtained from the crude oil ♦ 5 and the gas oil of the catalytic cleavage unit, as described in Comparative Example 1 - are mixtures the same amounts (percent by volume) of gas oil of the kata

Table III

dry gas example 1 Ver Example 3 Ver (m ^ m ³ ) ... gi.eichs- equal propane example 1 example : 55 Propylene 6o isobutane 26.4 27.0 η-butane 2.4 30.4 2.4 30.7 Butylenes 7.2 2.5 7th
7.1 2.5 C ₆ , 200 ⁰ C ... 5.6 7.0 5.8 7.5 200 to 32O ⁰ C 1.2 4.6 1.4 5.2 δ ₅ 320 ° C plus .. 6.4 1.2 3
6, p 1 3 coke 59.4 6.8 63.1 j., j
7.9 (Weighted 16.1 50.8 14.7 56.3 percent) ... 11.5 18.7 8.5 17.2 17.3 12.7 4.75 4.75 5.8 5.5

409523 /;

9 10

Is ^J) The catalytic cracking attempts related to the for product mixing and more herkömm-Erfindungsgegensiand vyerden in small, _Liche with a stationary bed uses in the refinery employed working laboratory reaction apparatus carried _, η l "i '" i. D · · N · j
leads. The yields are converted using the ^{crude oil according to} Example 1, along with unit factors, is defined as the yield in a refinery 15 volume percent of the condensate from the cooking unit / yield in the laboratory unit as narrower as it is fitted by conventional gauging to correspond to the yields that are obtained with a catalytic _{coke at} j ₅₂₀ ° C, together with the bottom cleavage unit of a refinery with fluidized bed under _c , .., _n , ..,. _n · ■ , -, .. “Similar conditions at approximately the same temperature to fraction from the crude oil according to Example 1, which are to be expected. In all examples the same set of the conditions of Example 1 of a Water Scope Unit Factor is used. has been subjected to treatment or hydrogenation,

10 a hydrogen treatment or hydrogenation and

lytic cleavage unit contained in crude oil, cleaved ¹ ). subjected to catalytic cleavage as in Example 1

The same do not give balanced descriptions in every case. The coking unit is at a

Gas oil flows again, since less gas oil, starting from a ^{bed temperature of 495 0} C with an input

treated with hydrogen from the hydrogenated or laßtemperatur the feed of 538 ⁰ C operated.

Feed, under equivalent cracking conditions 15 The ratio of oil to steam feed

is formed. The yields are in the following amounts to 20.5 volumes of oil per volume of water-

Table again as volume percent of the charge. The coking time is 9 hours. By

unless otherwise noted. the catalytic cracking of the 320 to 525 ° C gas oil

fraction obtained yields ¹ ), the gas oil

Comparative Example 1 ₂₀ f,. ^^ _from the hydrogenated mixture consisting of

It serves to demonstrate the crack yields such as 15 percent by volume of condensate from coking on hand of the conventional processing of device and 85 percent by volume of crude oil, gas oil, whereby one can refer to a sulfur-containing gas oil, see Table III.
Runs out of crude oil and does not proceed according to the invention. . . ,. . ,
The gas oil 25 described in Table I of Example 1, comparative example 2
is produced under the cleavage conditions of Example 1. This shows the lower yield of gasoline that cleave. The yields of cleavage products are shown in the table IN by conventional catalytic cleavage. The use of raw and coking gas oil resulted in 12 percent by volume of catalytic cracked gas oil in which no treatment with hydrogen or crude oil was equivalent to conventional catalytic hydrogenation.

see the splitting process in which the combined

feed ratio - total feed / fresh gas oil, see example 2, and 85 percent by volume crude oil,

loading - amounts to approximately 1.4: 1. A comparison, see Example 1, is distilled to obtain a

equal to the yields based on Example 1 and the gas oil fraction with a boiling range from 320 to

Comparative example 1 shows the markedly improved 35 525 "C. This gas oil is catalytically cracked, see

Conversion and selectivity in gasoline as well as Example 2. The yields are in Table III

reduced coke attack, as reproduced according to the invention. The yield of gasoline (C ₅ carbon

results. Hydrogen, 200 ⁰ Q is much less than at

B e i s D i e 1 2 using the method according to the invention in the

^p 40 Example 2, and the accumulation of coke is greater, whereby

This example shows the benefits of hydrogen- a greater loss of valuable products in shape

treatment or hydrogenation of the condensate of coke and thus a larger amount of air for the

Coking device displayed together with crude oil when the catalyst is regenerated,

the manufacture of a feed product for the r · 1 *

catalytic cleavage. 45 κ e 1 s ρ 1 e l j

With reference to FIGS. 3 is crude oil 10 In this embodiment, the heavy

as in FIG. 1 processed to get a gasoline reformed to make a gasoline higher

Bottom fraction 22, which is used as a feed for a her- octane number and hydrogen, which is used in the treatment

Conventional coking unit 60 is applied. can be used with hydrogen or hydrogenation

The 5 ° obtained by means of the coking unit 60 can.

Products consist of coke 64 and a hot coke. Referring to FIG. 2, crude oil 10 is vapor stream, which cools and then processed in the separation as in Example 1, the device 61 being converted into a gaseous stream 62, which is produced in the main column or columns 18 of the heavily essentials of hydrogen and C ₁ - to Ci -Carbon gasoline 20 is used as a feed for the catalytic reformation hydrogen, which is used in a gas concentration unit 50. The reforming plant for the purpose of separation and further processing consists of a hydrogenation reactor and leads to be split, and a liquid various reforming reactors together with stream 63, the furnaces and auxiliary equipment required essentially from Q-hydrocarbons. The substance and higher-boiling hydrocarbons up to the product stream is cooled and then in which there is a boiling point of about 510 ⁰ C and divided with 60 separating device 51 into a liquid product 52 higher than the octane number coming from the desalination device 11 and a gas stream 53, the over-crude oil stream is mixed. Optionally, it consists predominantly of hydrogen and partially fractionated as liquid product stream 63 or stream 54 can be returned to the reforming reactor and split up only a portion of this stream with and partially as stream 55 for use at the 65 exiting from the desalination device 11 elsewhere, e.g. . B. in the hydrogenation unit 15, partially stream are mixed, the remaining portion being withdrawn.

1 sheet of drawings

Claims (9)

l 2 patent claims · The invention relates to a process for the production of gasoline and refined liquid hydrocarbons 1. A process for producing gasoline and materials from a whole crude oil or a refined liquid hydrocarbons Removing crude oil that under removal of a-boiling below 200 ⁰ C? Ehend of a total crude oil or crude oil, 5 the fraction has been distilled, by means of Columns with removal of a ^{boiling below 200 0} C in a catalytic jig. Fraction has been distilled, by means of splitting According to the invention come closest in a catalytic splitting device, characterized by the state of the art (Austrian patent specification that the oil is a Hy- 285006) it is according to the so-called »J-splitting method using 240 to 1440 m ⁸ io ren «became known, a light catalytic gas oil hydrogen per m ^s oil at a temperature of 350 to 450 ⁰ C and a pressure of 17.5 to saturate with formation of a more easily cleavable 350 kg / cci ² in the presence of a hydrogenation hydrocarbon stream. For example, tetrahydrocatalyst can be subjected to fractionation, and naphthalene can be split much more easily than naphthalene, which is obtained in the subsequent fractionation Has a high proportion of aromatics and has a boiling range from 300 to 450 ° C coming from the catalytic cracking device. According to this, it is possible to return non-liquid products to the process, an untreated crude oil or a crude oil, by mixing with the starting oil before ao from which only the ^{boiling up to about 200 °} C. can easily be carried out the hydrogenation. volatile components have been removed, the other 2. The method according to claim 1, characterized by supplying marked processing. draws that the oil with 480 to 1190 m ^{3 of} water- To explain the further, more general substance per m ^{s of} oil at a temperature of 320 to the state of the art, it should be mentioned that it is known- 430 ⁰ C and under a pressure of 42 to 175 kg / 25 has become a separate hydrogen treatment cm ^{2 is} hydrogenated. or hydrogenation of catalytic fission product streams 3. The method according to claim 1, characterized marked to carry out, see z. B. the publication of draws that gasoline-containing liquid products R. A. F1 i η η and O. A. L a r s ο η »The Effects of from the catalytic cracking device partially Hydrogenation and Catalytic Cracking of Various are added to the oil before hydrogenation, 30 Molecular Types and Middle Distillates ", J. Appl. as well as at least a portion of that from Hydrier-Chem. 11, July 1961, pp. 271 to 276, and the publication device outgoing product is reformed by M.D.Abbott, R.C.Archibald. and R. W. Dο r η »Hydrogen Improves Catalytic 4. The method according to claim 1, characterized in “Cracker Feed”, Petroleum Refiner, 37, p. 161 to 166, records that the grain from the hydrogenation device 35 1958. menden products are fractionated, as well as we- The hydrotreatment or hydrogenation of at least a portion of the soil fraction is coked. Petroleum residues is in the following publications 5. The method according to claim 4, characterized thereby, described (Dutch patent specification records that at least a portion of the liquid 6,916,218-Q). Here are methods of converting Products from the coking device into the 40 sulfur-containing, carbon-containing black oils in Process is recycled with mixing low boiling, normally liquid hydrocarbons the oil fed to the hydrogenation. Substance products with a reduced sulfur content 6. The method according to claim 1, characterized in that an integrated method for marking that a metal is used as a hydrogenation catalyst, in which splitting occurs in the presence from the group of nickel, molybdenum, cobalt and 45 hydrogen and a catalytic desulfurization Tungsten or a these metals containing Ver in a stationary bed takes place. The Dutch patent binding is applied. 6 916 017-Q teaches the hydrodesulphurisation of 7. The method according to claim 1, characterized in crude oil or reduced crude oil, the asphalt fractions draws that both a gas oil and a medium contains, at low temperatures in distillate-containing liquid products of the cataly- 50 presence of a metal catalyst of groups VI / table splitting device for the oil in front of the hydration VII of the periodic table arranged on alumina, tion is supplied. The hydrotreatment or hydrogenation of the 8. The method according to claim 1, characterized total crude oil is described in detail in a draws that at least a portion of the water publication by S. G. Parad is, G. D. Gould, Substance in the process to the hydrogenation device 55 D. A. B e a and E. M. R e e d with the designation tung returned wild. "Isomax Desulfurization of Residium and Whole 9. The method according to claim i, characterized marked Crude Oil «, which was held as lecture 31c, that the hydrogenated product in several venues of the meeting of the American Institute of Chemical Hydrocarbons and a Ground Fraction Engineers February 28 to March 4, 1971 in Houston, tion is fractionated, as well as at least a portion 60 U.S. Patent 3,562,800 deals with the the bottom fraction in a coking device hydrodesulphurisation of crude oil or reduced oil is coked, the liquid coking product in oil without returning liquid products from others a top distillate with Q hydrocarbons and units mixing with the incoming lighter hydrocarbons and at least crude oil feed. a high-boiling stream with C ₅ hydrocarbons 65 The object of the invention is to provide a substances and heavy hydrocarbons frak- process of the specified type to create it is operated. enables, with reduced device and flawed effort, starting from crude oil,