Hydrogenation of middle distillate in countercurrent reactor

FIELD: petrochemical processes.

SUBSTANCE: major amount of hydrocarbon stock is brought into countercurrent contact with hydrogen in first reaction zone under hydrogenation reaction conditions in presence of hydrogenation catalyst in at least first catalyst bed wherein liquid leaving stream comes out of the bottom of the first reaction zone and hydrogen-containing gas stream comes out of the top of the first reaction zone. After that, insignificant part of hydrocarbon-containing stock comes into contact with above-mentioned hydrogen-containing gas stream in the second reaction zone accommodating catalyst bed disposed in such a way as to receive hydrogen-containing stream from the first reaction zone.

EFFECT: enabled production of product with ultralow content of sulfur using simple processing flowsheet.

19 cl, 7 dwg

The invention relates to a method of hydrogenation of the raw materials of the middle distillate such as diesel fuel, to get diesel product of improved quality.

The level of technology

Petroleum distillates, including gas oil, boiling in the range of from about 165°up to about 426°including straight-run gas oils, gasoil, light thermal cracking, oil coking and light cycle gas oil from fluid-catalytic cracking (FCC)process to obtain a diesel fuel of improved quality. Diesel fuel must meet certain specifications regarding the content of sulfur, nitrogen, olefins and aromatics, cetane index, boiling point (distillation) and density. Stricter rules will require refiners in subsequent years to produce diesel fuel with ultra-low sulfur content (TONS). In General this will force refiners to produce diesel fuel with a sulfur content of 0.001-0.005 wt.%.

Desulphurized hydrocarbon Hydrotreating, i.e. by reaction with hydrogen under appropriate conditions to remove sulfur in the form of hydrogen sulfide (H₂S). With the current advances in catalysis in existing installations, refiners can reduce the sulfur content in the treated distillate, but insufficient is about, to meet the requirements.

Many existing Hydrotreating unit, which currently produce diesel fuel with sulfur levels greater than 50 weight parts per million, require reconstruction and/or new implementation. In order to achieve the required technical specifications for diesel fuel, must be processed distillate feedstock to affect the chemical and physical properties of the distillate. The type of catalyst and the operating conditions depend on the specifications for diesel fuel. Processing requires hydrogenation with an appropriate catalyst, or a combination of different catalytic systems in the atmosphere, enriched with hydrogen. To reduce sulfur, nitrogen, olefins and aromatic compounds requires deep hydrogenation. To improve the cetane number and/or density is required as deep hydrogenation and selective ring opening.

Reconstruction of existing facilities Hydrotreating to produce diesel fuel with ultra-low sulfur conventional processing previous practice will usually add a new flow reactor in series or parallel to an existing reactor to provide additional volume of catalyst. In addition, this type of reconstruction scheme offers significant the modification and/or replacement of existing equipment in the reaction loop high pressure, including the main pipe/heat exchanger, amine scrubber and the compressor recirculatory. All these modifications of existing facilities will result in significant capital and downtime.

The invention

Presents a method for hydrogenation of hydrocarbons. The method provides for countercurrent contacting of the main part of the hydrocarbon feedstock with hydrogen in a first reaction zone under reaction conditions of the hydrogenation in the presence of a hydrogenation catalyst, at least in the first catalyst layer, in which the liquid flow out from the bottom of the first reaction zone and a gaseous stream containing hydrogen, released from the top of the first reaction zone; and direct contacting a minor portion of hydrocarbons with the specified gaseous stream in a second reaction zone having a catalyst layer located so as to receive a stream containing hydrogen from the first reaction zone.

In another embodiment, the method involves: a) direct contact of the petroleum fraction with hydrogen in a first reaction zone in the presence of a first hydrogenation catalyst to obtain a first stream having a reduced content of heteroatoms; and (b) countercurrent contacting the first stream with hydrogen in a second reaction zone in the presence of vtoro what about the hydrogenation catalyst, in order to obtain a product having a content of heteroatoms just about to 0.005 wt.%.

The method leads to a deep hydrogenation and allows you to get diesel fuel with ultra-low sulfur content on new and existing equipment without major changes normally associated with conventional recycling schemes.

Brief description of drawings

Figure 1 shows a schematic diagram of the process according to the invention that use once-through reactor in combination with a new counter-flow reactor according to the invention;

Figure 2-4 - schematic diagrams other diagrams of the process according to the invention, using both straight-through and a new counter-flow reactors;

Figure 5 - schematic diagram of the process of hydrogenation of petroleum distillate, using only a counter-current reactor;

Figure 6 - chart subsequent dearomatization processing that can be performed on the product of the method of hydrogenation according to the invention, and

7 is a schematic illustration of a multilayer countercurrent reactor according to the invention.

A detailed description of the preferred option implementation

The present invention can be used for the hydrogenation of petroleum fractions, especially middle distillate, which can be used for diesel fuel. The hydrogenation can use the with for Hydrotreating, for example, removal of heteroatomic or aromatic compounds (for example, hydrodesulphurization unit, gidrogenizirovanii, hydrodearomatization).

The processing circuit of the present invention uses a counter-current reactor, which can be integrated into the existing system Hydrotreating. Countercurrent reactor perform "outside the reaction loop high pressure", thus offering additional benefits, including lower installation costs, a simpler reconstruction, no integration of the main pipe/heat exchanger, no strong impact on the existing scrubber or compressor recycle gas and reduce downtime. Additional scheme uses a catalyst low value on the basis of base metal and offers improved product properties, including reducing the content of aromatic compounds, the improvement of cetane number and stability of the catalyst.

During the reconstruction of the existing reactor is optimized to prepare raw materials for the new counter-current reactor. Later in countercurrent reactor stream from an existing reactor is processed in such a way as to achieve the desired goals.

Figure 1 shows a system 100 hydrodesulphurization unit of the middle distillate. System 100 shows reconstru the tion scheme Hydrotreating, circled circuit 101, by incorporating circuit 102 countercurrent reaction. In the following description similar numeric and alphanumeric designations indicate similar equipment or process flows.

Raw F - medium oil fraction, usually having the properties shown in Table 1:

These intervals are presented for the purpose of illustration. Raw materials having properties outside these limits may also be used, if appropriate.

Hydrogen is added to the raw material F on the line 127 and the mixture of raw materials-hydrogen served in a once-through reactor R-1, which is achieved at least a partial desulfurization. Once through the reactor includes a layer containing a suitable desulfurization catalyst, such as Nickel (i), cobalt (Co), molybdenum (Mo), tungsten (W) and their combination (such as Ni-Mo, Co-Mo, Ni-W, Co-Mo-Ni, Co-Mo-W) on a carrier such as silica, alumina or silica-alumina. The flow conditions of the desulfurization reaction usually include a temperature of from about 200°With up to 450°C, a pressure from about 21,09 to about 105,5 MPa and a space velocity of up to about 20 h^-1. Stream 110 from the reactor R-1 typically contains from about 0.01 to about 0.1 wt.% sulfur. At least partially desulfuromonas stream (line 110) is cooled in the heat exchanger 111 to a temperature of from about 200°C to about 380°and serves on line 110 to the separator D-11, where it is separated into vapor and liquid. The liquid away on the line 112 is heated in the heat exchanger 113 to a temperature of from about 225°up to about 370°and served in a counter-current reactor R-2. A pair of separator D-11 is cooled further in heat exchanger 115 and serves on line 114 to the separator D-12 for further separation of the steam and liquid components. Fumes containing hydrogen, hydrogen sulfide and light hydrocarbon components, add on line 120 to line 118 to transfer to the separator D-13. Liquid divert and serves on line 122 in stream 112, arriving in reactor R-2.

Countercurrent reactor R-2 preferably contains two or more layers of catalyst B-1 and b-2. Reactor R-2 contains two reactive C the us: the first zone, in which the hydrocarbon and hydrogen are contacted counter-current, and a second reaction zone in which the hydrocarbon and hydrogen in contact with a co-current. As shown in Fig. 1, the layer-1 is in the first reaction zone, and the layer-2 - in the second reaction zone. The hydrocarbon raw material is introduced into the reactor R-2 is in position between the first and second reaction zones. Each layer contains a catalyst hydrodesulphurization unit. Useful catalysts for hydrodesulphurization unit include catalysts mentioned above (for example, Ni-Mo, Co-Mo, Ni-W on the carrier of silica, alumina or silica-alumina), as well as zeolites, precious metals and other Liquid raw materials in line 112 is introduced into the reactor R-2 between layers B-1 and b-2. Conforming hydrogen is introduced into reactor R-2 below. Reactor R-2 operates at a temperature of from about 225°With up to 450°C, a pressure of from about 17,58 to about 105,5 ATI and volume rate of from about 0.6 to about 5.0 HR^-1.

The main part of the hydrocarbons in the reactor flows from top to bottom in the first reaction zone occupied by the layer-1. Hydrogen is included in the reactor R-2 from the bottom, flows through the layer-1 catalyst upward countercurrent with respect to the liquid raw material. However, the hydrogen-containing gas discharged from the layer-1 from the top of the first reaction zone, captures a small part of hydrocarbon materials which, received into the reactor. Any captured hydrocarbon mist or vapor reacts with the hydrogen-containing gas in the presence of a catalyst layer-2. As the hydrocarbon portion and the hydrogen-containing gas flowing upwards through the layer-1, the contacting is carried out straight. The location of the catalyst layer In a-2 above the point of entry of raw materials to make a stream of hydrogen containing gas from the first reaction zone, ensures that the hydrocarbons are not passed through the reactor R-2, not contacting with hydrogen in the presence of a catalyst; thereby achieves ultra-low sulfur level. Head product 116 from the reactor R-2 is combined with the liquid flowing from the lower part of the reactor, and the total flow from the reactor R-2 is cooled in heat exchanger 117 and serves on line 118 into the separator D-13.

Liquid product P is separated and away from the separator D-13 through line 126 and the pair is removed by line 124. The method and equipment described here will provide the product P, is useful as a component of diesel fuel with sulfur content below 0.005 wt.%.

Pairs taken from the top of separator D-13 (containing hydrogen, hydrogen sulfide and some of the hydrocarbon components), divert on line 124 and served through the heat exchanger 125 for cooling and then through the installation of 130 air cooling in separator D-14 draft a separation of liquid and vapor. The liquid from separator D-14 away from the bottom line 134 and add to the stream 126 with obtaining flow R product oil fraction with a low sulfur content. A pair of separator D-14 (containing hydrogen, hydrogen sulfide and some of the hydrocarbon components, such as methane, ethane and other) available on line 132 in the lower part of the absorber And in which the upward flow of vapor countercurrent contact with the descending adsorbent to remove the hydrogen sulfide from the vapor stream. More specifically, weak amine absorbent a-1 is injected from the top of the absorber 150. Amine absorbent is preferably, for example, an aqueous solution of alkanolamine, such as ethanolamine, diethanolamine, diisopropanolamine, methyldiethanolamine, triethanolamine and the like substances.

Rich in hydrogen pairs taken from the top of the absorber And containing a certain amount of light hydrocarbon components), available on line 136 into the compressor C-1, where komprimiert to pressure from about 28,12 to about 112,5 ATI. Stream 128, coming out of the compressor C-1, can be divided into stream 129, which is mixed with the stream of conditioned hydrogen feed to the reactor R-2, and stream 127, which serves through the heat exchanger 125 flow 124 in the flow F of raw materials.

In figure 2, the system 200 illustrates the reconstruction scheme Hydrotreating, ochotorena line 201, enabling the counter is full reaction scheme 202. Raw material F having the composition specified above, is combined with the hydrogen and light hydrocarbons) from the stream 238 and then fed to the reactor R-1, which is at least partially hydrodesulphurization unit in the reaction conditions set forth above. The resulting stream 210 from the reactor R-1 is cooled in heat exchanger 211 and served in separator D-21, where liquid and vapor are separated. The vapor stream 226 of the separator D-21 is fed through the heat exchanger 227 and cooler 230 in separator D-24. Liquid flowing from the lower part of the separator D-21, divert on line 212 and add to the stream 214 from the separator D-24, which is then fed into the reactor R-2 through an optional pump 215 and the heat exchanger 216. The heat exchanger 216 regulates the temperature of the stream 214 to a temperature of from about 200°With up to 450°C. As described above, the raw materials into the reactor R-2 is injected between the layers of catalyst B-1 and b-2. The fluid flows through the layer-1 from top to bottom relative to the upward flow of hydrogen. The upward flow of fog trapped hydrocarbons further processed in layer-2. Pairs taken from the top and containing hydrogen, hydrogen sulfide and hydrocarbon components, combined with the liquid from the bottom of the reactor R-2 with a receiving stream 218. Full stream 218 from the reactor R-2 is cooled in the heat exchanger 219 and served in the sump D-22. The product P in the form of liquid from the sump D-22 flows from the top down. Pairs of OTS is Eunice D-22 is further cooled in heat exchanger 223 and served in separator D-23 for further separation. The liquid from the lower part of the separator D-23 serves on line 222 to line P of the product oil fraction with a low sulfur content. Stream 224, taken from the top, add to the vapor stream 226 of the separator D-21. As mentioned above, the stream 226 is cooled in the heat exchanger 227, then cooled in the air cooler 230 and served in separator D-24. Liquid flowing from the lower part of the separator D-24, is fed into reactor R-2 through line 214. Pairs taken from the top of separator D-24 and containing hydrogen, hydrogen sulfide and light hydrocarbons, is fed into the absorber And where they countercurrent contact with the descending amine absorbent of hydrogen sulfide, such as described above. Stream 232, taken from the top, not containing hydrogen sulfide and containing mostly hydrogen and some light hydrocarbons, is fed into the compressor 1 and komprimiert to pressure from about 28,12 to about 112,5 ATI. Output 234 of the compressor can be divided into stream 236, which is added to the stream of conditioned hydrogen, and stream 238, which exchanges heat with the stream in the heat exchanger 226 227 and which is then added to the flow F of the raw material for introduction into reactor R-1.

In figure 3, the system 300 illustrates the reconstruction scheme Hydrotreating, ochotorena line 301, the inclusion of a counter-current reaction scheme 302. Raw material F having the composition specified above, is combined with stream 342, soderzhimogo and a certain amount of light hydrocarbon components, and injected into the reactor R-1 for at least partial hydrodesulphurization unit in the reaction conditions set forth above. The resulting stream 310 from the reactor R-1 is cooled in the heat exchanger 311 and served in separator D-31 for separation of liquid and vapor. The liquid serves on line 312 in reactor R-2 is optional through the pump 314 and the heat exchanger 315. The heat exchanger 315 regulates the temperature of the stream 312 to a temperature of from about 200°With up to 450°C. As described above, the raw materials into the reactor R-2 is injected between the layers of catalyst B-1 and b-2. The fluid flows down through the layer-1 relative to the upward flow of hydrogen. Conforming hydrogen from the hydrogen source is introduced below the layer-1 and flows upwards. The upward flow of fog trapped hydrocarbons further processed in layer-2. Pairs taken from the top and containing hydrogen, hydrogen sulfide and a couple of hydrocarbons combine with the liquid flowing from the bottom of reactor R-2. Full stream 318 from the reactor R-2 is cooled in the heat exchanger 319 and served in the sump D-32. Fluid from the sump D-32 assign line 322, which is added to the fluid flowing from the lower part of the separator D-33, receiving stream 328. Stream 328 is added to the stream 344 of the separator D-34 with receiving stream P of the product. Stream 320 vapors from separator D-32 is further cooled in the heat exchanger 321 and served in separator D-33 for further separation. The Jew is the beginning flowing from the bottom of separator D-33, available on line 324 to the stream 322, as described above. Stream 326 vapor selected from the top of separator D-33 add to the stream 334 of the separator D-34.

Stream 313 vapors from separator D-31 is cooled by heat exchange in the heat exchanger 325 and further cooled by the cooler 330 prior to being fed into the separator D-34 for separation of vapor and liquid. Liquid stream 344 of the lower part of the separator D-34 combined with the liquid stream 328 of the separator D-32 receiving stream R product oil fraction with a low sulfur content. Steam flow, selected from the top of separator D-34, together with a steam stream 326 of the separator D-33 and serves on line 334 in the absorber And in which he countercurrent contact with a descending stream of amine absorbent of hydrogen sulfide, such as described above. Steam flow 336, selected from the top and not containing hydrogen sulfide and containing mainly hydrogen and minor amounts of light hydrocarbons, is fed into the compressor C-1 for the compression up from about 28,12 MPa to about 112,5 ATI. Output 338 of the compressor can be divided into stream 340, which is added to the stream of conditioned hydrogen, and stream 342, which is subjected to heat exchange with the stream 313 in the heat exchanger 325 and then served in the commodity flow F for introduction into reactor R-1.

In figure 4, the system 400 illustrates the reconstruction scheme is s Hydrotreating, contentnow line 401, the inclusion of a counter-current reaction scheme 402. Raw material F having the composition specified above, is combined with stream 434 containing hydrogen and a certain amount of light hydrocarbon components, and injected into the reactor R-1 for at least partial hydrodesulphurization unit in the reaction conditions set forth above. The resulting stream 410 from the reactor R-1 served in the separator D-41. Liquid flow 414 arising from the lower part of the separator D-41, is cooled in the heat exchanger 413. Steam stream 412, selected from the top, together with a liquid stream 414, which is then fed into the reactor R-2. As described above, the raw materials into the reactor R-2 is injected between the layers of catalyst B-1 and b-2. The fluid flows down through the layer-1 relative to the upward flow of hydrogen. Conforming hydrogen from the hydrogen source is introduced below the layer-1 and flows upwards. The upward flow of fog trapped hydrocarbons further processed in layer-2. The resulting stream 418 of the lower part of the reactor R-2 is available on line 418 through the cooler 417 in separator D-42. Steam flow 416, taken from the top of the reactor R-2, add to the stream 418 before cooling in the cooler 417. Fluid from the lower portion of the separator D-42 assign line 422, and they become a stream R product. Stream 420 vapors from the upper part of the separator D-42 is cooled by heat exchange in the heat exchanger 425 and then cool vozduhoohladiteli who eat 430 prior to being fed into the separator D-43 for further separation of vapor and liquid. Liquid flow 424 of the lower part of the separator D-43 combined with liquid stream 422 of the separator D-42 with obtaining flow R product oil fraction with a low sulfur content. Steam flow from the upper part of the separator D-43 serves on line 426 in the absorber And in which he countercurrent contact with a descending stream of amine absorbent of hydrogen sulfide, such as described above. Steam flow 428, selected from the top and not containing hydrogen sulfide and containing mainly hydrogen and minor amounts of light hydrocarbons, is fed into the compressor C-1 for the compression up from about 28,12 MPa to about 112,5 ATI. The output stream of the compressor is divided into a stream 432, which is added to the stream of conditioned hydrogen, and stream 434, which is subjected to heat exchange with the stream in the heat exchanger 420 425, and then served in the commodity flow F for introduction into reactor R-1.

Figure 5 shows a system 500 in which once-through reactor R-1 is not used to pre-process raw materials with the aim of partial Hydrotreating. Preferably, only the reactor R-2 is used for the hydrogenation. Raw material F is heated in the heat exchanger 510, then in the heat exchanger 512, and then serves to further heating to a temperature of from about 200°With up to 450°C heater 514. The heated raw material is then injected into the reactor R-2 at a point between layers B-1 and b-2, as explained above the axle above. Stream 529 hydrogen is introduced into the bottom of reactor R-2 and flows from the bottom to the top of the descending liquid petroleum distillate. As described above, the captured hydrocarbons carried by the ascending gas, included in the layer-2 and subjected to Hydrotreating in such a way that no portion of raw material F is not released from the reactor R-2 without Hydrotreating. Stream 516, selected from the top of the reactor R-2, is cooled in the heat exchanger 510 by heat exchange with incoming raw F and then fed to the separator D-51 for separating liquid and vapor. Fluid flowing from the lower part of the separator D-51, available on line 520 to connect with stream 534 (liquid from the lower part of the separator D-53), in order to ensure the flow P of the product. Steam flow 518 of the upper part of the separator D-51, containing hydrogen, hydrogen sulfide and some light hydrocarbons, is fed into the absorber And in which the ascending vapor in contact with a downward weak amine absorbent a-1 of hydrogen sulfide. Steam flow 522 of the upper part of the absorber And not containing hydrogen sulfide and containing hydrogen and a certain amount of light hydrocarbons, together with a conforming hydrogen from the hydrogen source and fed into the compressor C-2/C-3 for compression. Stream 532 of the upper part of the separator D-53 combined with the output stream of the compressor C-2 to form stream 523, which is cooled in the heat exchanger 524 and the eating serves to separator D-52 for further separation of liquid and vapor. Fluid from the lower portion of the separator D-52 serves on line 528 to the stream 534 arising from the lower part of the separator D-53, in order to ensure that the product P with ultra-low sulfur content. The 529 flow from the upper part of the separator D-52 served in the compressor 3 for compressing and then fed to the bottom of the reactor R-2. Full compression between C-2 and C-3 is from about 21,09 MPa to about 112,5 ATI.

Figure 6 shows how the product P with ultra-low sulfur content can be gidrirovanny next. For example, the system 600 includes a reactor 610 of hydrodearomatization containing layer-3 catalytic hydrogenation. The reactor typically operates at a temperature of from about 200°With up to approximately 400°C, a pressure of from about 28,12 MPa to about 112,5 MPa and a flow rate from about 0.3 h^-1to about 6 h^-1preferably about 3.5 h^-1. Various hydrogenation processes are known and described, for example, in U.S. patent No. 5183556, which is included in the review links. The catalyst layer-3 may be noble or base metal, deposited on silicon dioxide, aluminum oxide, silicon dioxide-aluminum oxide, zirconium oxide or another metal oxide. Hydrogen from the hydrogen source is introduced into the bottom of the reactor 610 and flows upward relative to the downstream fraction of petroleum distillate. Steam flow from the upper part of the remove Linyi, and the flow coming from the lower part, containing dearomatizing petroleum distillates, remove line 603.

7 illustrates the alternate multilayer countercurrent reactor R-3 hydrogenation. Reactor R-3 contains three space-separated catalyst layer (b-1A, B-1b and b-2). Raw material F is injected between the middle layer b-1b and the upper layer b-2. Hydrogen is injected along the lines N-1 and N-2. The log N-1 in reactor R-3 is located below the lower layer b-1A and N-2 in the reactor R-3 is located above layer 1A and the lower layer B-1b. The hydrogen flows upward relative to the downward flow of the raw material F oil distillate and hydrogenation of the feedstock F (for example, the hydrodesulphurization unit, gidrogenizirovanii) is performed in layers b-1A and b-1b counterflow contact with hydrogen. As mentioned above, a number of hydrocarbon components can be captured by the rising stream of hydrogen and these components hydronauts in layer-2, so that all the raw materials are subjected to hydrogenation. Steam flow (V) of the upper part of the layer-2 contains an excess of hydrogen, hydrogen sulfide and some amount of light hydrocarbon components. Liquid output stream E, taken from a bottom of the reactor, contains petroleum distillates (such as diesel fuel with ultra-low sulfur content.

The example below illustrates aspects of the invention.

The material had the following properties:

Raw materials are treated in the system hydrogenation with a counter-current reactor according to the invention. Reaction conditions include a temperature of 346°C, pressure 52,73 MPa, space velocity of 1.6 h^-1and a hydrogenation catalyst NiMo media silicon dioxide. The reaction product had a density of 38.6 degrees ANI, the sulfur content 0,0008% wt. and the nitrogen content is less than 0.0001 wt.%.

Although the description above contains many specifics, these specifics should not be construed as limiting the scope of the invention, but merely as illustrative examples of its preferred options. For example, the first and second reaction zones may be located in different reactors or in a single reactor. Experts, experienced in the technique, you can anticipate many other possible variations that satisfy the scope and essence of the invention defined by the attached formula the image is to be placed.

1. The method of hydrogenation of hydrocarbons, which comprises contacting the main portion of the hydrocarbon feedstock with a hydrogen flow in the first reaction zone at reaction conditions of the hydrogenation in the presence of a hydrogenation catalyst in at least the first catalyst layer, in which the liquid flow out from the bottom of the first reaction zone and a gaseous stream containing hydrogen, released from the top of the first reaction zone and in direct flow communication minor portion of hydrocarbons with the specified gaseous stream containing hydrogen in a second reaction zone having a catalyst layer located so as to receive a stream containing hydrogen from the first reaction zone.

2. The method according to claim 1, in which the first and second reaction zones are in the first reactor in which the catalyst bed of the second reaction zone is located above the first layer of the catalyst of the first reaction zone and the hydrocarbon feedstock is introduced into the first reactor at a position between the first layer of the catalyst of the first reaction zone and the catalyst bed of the second reaction zone.

3. The method according to claim 2, in which at least some amount of hydrogen introduced into the reactor below the first layer of the catalyst of the first reaction zone.

4. The method according to claim 2, in which the second catalyst bed is below the PE the first layer of the catalyst of the first reaction zone.

5. The method according to claim 4, in which at least some amount of hydrogen introduced into the reactor below the second layer of the catalyst of the first reaction zone and at least some amount of hydrogen introduced into the reactor between the second catalyst layer and the first layer of the catalyst of the first reaction zone.

6. The method according to claim 2, including the preliminary processing of hydrocarbon raw materials in the second flow reactor by contacting the hydrocarbon feedstock with hydrogen in the presence of a hydrogenation catalyst.

7. The method according to claim 1, in which the specified hydrocarbon feedstock contains sulfur and/or nitrogen.

8. The method according to claim 7, in which the hydrocarbon feedstock has a sulfur in the initial percentage composition, the method of hydrogenation is a hydrodesulphurization unit and the method produces a product containing sulfur only about 0.001 wt.%.

9. The method according to claim 1, in which the method of hydrogenation is hydrodearomatization.

10. The method of hydrogenation of petroleum fractions which comprises (a) a direct contacting a petroleum fraction with hydrogen in a first reaction zone in the presence of a first hydrogenation catalyst to produce the first output stream with reduced content of heteroatoms; and (b) contacting the first effluent stream with hydrogen in a second reaction zone in the presence of the second catalyst selective the project, to obtain a product containing heteroatoms just about to 0.005 wt.%, the first output stream is injected into the second reaction zone between the first and second catalyst layers, wherein said incoming stream flows down through the first layer of the catalyst relative to the rising hydrogen-containing gas, and in which a small part of the incoming stream is captured by an ascending stream of hydrogen containing gas to the second catalyst bed.

11. The method according to claim 10, in which the oil phase is a middle distillate having an initial boiling point of from about 165 to about 260°and an end boiling point of from about 280 to about 440°C.

12. The method according to claim 10, in which the reaction conditions of the first hydrogenation include a temperature of from about 200 to about 450°C, a pressure from about 21,09 to about 105,5 MPa and space velocity from about 0.4 to about 20 h^-1.

13. The method according to claim 10, in which the reaction conditions of the second hydrogenation include a temperature of from about 225 to about 450°C, a pressure from about 17,58 to about 105,5 MPa and space velocity from about 0.4 to about 10 h^-1.

14. The method according to claim 10, in which the catalyst of the first hydrogenation includes one or more metals selected from the group consisting of cobalt, molybdenum, Nickel and tungsten on a carrier is utilizator.

15. The method according to 14, in which the catalyst carrier is an inorganic oxide selected from the group consisting of silicon dioxide, aluminum oxide, silicon dioxide-aluminum oxide, zirconium oxide and titanium oxide.

16. The method according to claim 10, in which the catalyst in the second hydrogenation includes one or more metals selected from the group consisting of cobalt, molybdenum, Nickel and tungsten on a carrier of a catalyst.

17. The method according to clause 16, in which the catalyst carrier is an inorganic oxide selected from the group consisting of silicon dioxide, aluminum oxide, silicon dioxide-aluminum oxide, magnesium oxide, zirconium oxide and titanium oxide.

18. The method according to claim 10, in which the heteroatom is sulfur, and the reaction of the hydrogenation reaction hydrodesulphurization unit.

19. The method according to p, in which the sulfur content in the product is less than 0.001 wt.%.