KR101070519B1 - Hydrogenation of middle distillate using a counter-current reactor - Google Patents

Abstract

Hydrogenation of hydrocarbon materials involves hydrogenation in which the hydrogenation catalyst is present in the first catalyst bed such that the liquid effluent exits the bottom tip of the first reaction zone and the hydrogenous gaseous effluent exits the top of the first reaction zone. Under reaction conditions, a major portion of the hydrocarbon material is in contact with hydrogen in a countercurrent manner in the first reaction zone and in a cocurrent manner in a second reaction zone having a catalyst bed arranged to receive the hydrogenated effluent of the first reaction zone. Contacting a small portion of a hydrocarbon material with said hydrogenous gaseous effluent.

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Description

HYDROGENATION OF MIDDLE DISTILLATE USING A COUNTER-CURRENT REACTOR}

The present invention relates to a process for hydrogenation, ie hydrogenation of middle distillate feedstocks, such as diesel fuel, for making qualitatively improved diesel products.

Petroleum classification including boiling gas oils in the range of about 330 ° F. to about 800 ° F., diesel diesel, thermally split diesel fuel in a visbreaker, diesel fuel cokers and circulating diesel fuels (FCCs). Water is used to produce qualitatively improved diesel fuel. The diesel fuel should meet the characteristics relating to sulfur, nitrogen, olefin and aromatic content, cetane index, boiling point (distillation) and gravity. More stringent rules will be required of refiners to produce ultra low sulfur diesel (ULSD) in the near future. Generally, this will be required of the refiner to make diesel fuel containing 10 wppm to 50 wppm or less sulfur.
The removal of sulfur in hydrocarbon fuels by treatment of hydrogen is already known, ie, reacting the fuel with hydrogen under appropriate conditions to remove sulfur in the form of hydrogen sulfide (H ₂ S).
With recent improved catalysts, refiners can reduce the sulfur in the purified distillate in the units presently present, but not to the point of regulation.
Many existing hydroprocessing plants currently produce diesel fuel containing more than 50 wppm of sulfur, requiring improvements or implementation of new units.
In order to achieve the required diesel fuel specifications, it is necessary to process the sorting feedstock to affect the chemical and physical properties of the fraction.
The type of catalyst and the rigor of its operation is a function of the desired diesel fuel specification.
The process requires hydrogenation with a suitable catalyst or combination of other catalyst systems in a hydrogen rich environment.
For hydrogen, nitrogen, olefins and aromatics reduction, deep hydrogenation is required.
In order to improve cetane and / or specific gravity, deep hydrogenation and selective ring opening are required.
Previously implemented traditional methods designed to improve existing hydroprocessing plants that produce extremely low sulfur diesels include the addition of side-by-side or co-current reactors with existing reactors. In addition to implementing the catalyst volume.
In addition, modifications of this type take the form of replacements or significant modifications of current equipment items in high pressure reaction circulation (LOOP), including main piping / heat exchangers, amine scrubbers and recycle compressors. All changes to these current units will result in more capital investment and downtime.

In the present invention, a hydrogenation method of a hydrocarbon material is provided. The method comprises contacting a major portion of a hydrocarbon material with hydrogen in a countercurrent method in a first reaction zone under conditions of a hydrogenation reaction in which a hydrogenation catalyst is present in a first catalyst bed, wherein the first reaction zone A gaseous hydrogen-containing effluent is discharged at the top end of the gas and a liquid effluent is discharged at the bottom end of the first reaction zone;
Contacting a small portion of the hydrocarbon material with the gaseous hydrogen effluent in a forward, cocurrent manner in a second reaction zone having a catalyst bed arranged to receive the hydrogen effluent of the first reaction zone.
In another embodiment, (a) contacting petroleum fractions in parallel with hydrogen in a first reaction zone in the presence of a first hydrogenation catalyst to produce a first effluent having a reduced heteroatom content. ; And (b) contacting the first effluent with hydrogen in a second reaction zone in a second reaction zone in the presence of a second hydrogenation catalyst to produce a product having a hetero atom content that does not exceed about 50 ppm in weight. do.
The above methods involve deep hydrogenation and, in conjunction with conventional process regimes, realize a diesel fuel containing extremely low sulfur, generally in both new and existing plants, without major modifications.

Various embodiments are described below with reference to the figures, in which:

1 is a schematic diagram of the process of the present invention using a forward reactor with the novel countercurrent reactor of the present invention.

2-4 are schematic diagrams of an overview of another process of the present invention using both forward and novel countercurrent reactors.

FIG. 5 is a schematic diagram of a process overview for hydrogenation of petroleum distillate using only a countercurrent reactor.

FIG. 6 is a subsequent dearomatization treatment diagram that may be performed in the output of the hydrogenation process of the present invention.

7 is a schematic illustration of a multi-phase countercurrent reactor of the present invention.

The present invention can be used for hydrogenation of middle fractions, ie effluents, such as those used for petroleum fractions, in particular diesel fuels. Hydrogenation can be used, for example, in hydrotreating to remove hetero atoms or in dearomatization (eg, hydrodesulfurization, hydrodenitrification, hydrodesorption).
The process summary of the present invention uses a countercurrent reactor that can be integrated into current hydrogen treatment systems. The counterflow reactor is installed outside the “high pressure reaction loop” to provide lower installation costs, simpler modifications, non-mainstream main piping / heat integration, conventional scrubber or recirculating gas compressors. There is no impact on the compressor and provides additional process gains including reduced downtime. This alternative overview uses low cost base metal catalysts and provides improved product features including reduced aromatics, improved cetane and stability of the catalyst.
In the retrofit, the existing reactor operation is optimized to prepare the material with a new countercurrent reactor. The countercurrent reactor also treats effluent from existing reactors to achieve the desired process objectives.
Referring to FIG. 1 provided, system 100 shows hydrodesulfurization of an intermediate effluent. System 100 describes a modification of the hydroprocessing arrangement, separated by the outline of reference numeral 101 by the combination of countercurrent reaction scheme 102. In the following description of the remaining figures, the same reference numbers and signs represent the same processing apparatus or flow.
The feed, F, is generally a medium range petroleum fraction having the following characteristics shown in Table 1:
Table 1
API Gravity 20-45
Distillation Range ℃ (℉)
Initial boiling point 165-260 (330-500)
Final boiling point 280-440 (536-825)
Sulfur, wt% 0.01-2.0
Nitrogen, (total) wppm 15- 1000
Bromine number, g / 100g 1-10
Cetane Index 25-55
The above ranges are given for illustrative purposes. Materials having features outside the range may also be used as appropriate.
Hydrogen is added to material (F) via line 127, and the hydrogen added to the mixed material is sent to a co-current reactor (R-1), where at least partial hydrodesulfurization takes place. The cocurrent reactor is a carrier such as silica, alumina, or silica-alumina, i.e., on a support, nickel (Ni), cobalt (Co), molybdenum (Mo), tungsten (W), and combinations thereof (Ni-). Bed comprising an appropriate hydrodesulfurization catalyst such as Mo, Co-Mo, Ni-W, Co-Mo-Ni, Co-Mo-W, and the like. Cocurrent hydrodesulfurization reaction conditions generally include a temperature of about 200 ° C. to about 450 ° C., a pressure of about 300 psig to about 1,500 psig, and a space velocity of less than about 20 v / v / hr. do. Effluent 110 from reactor R-1 generally contains about 100 ppm to about 1,000 ppm of sulfur by weight. The effluent at least partially desulfurized (line 110) is cooled, ie cooled, by the heat exchanger 111 to a temperature of about 200 ° C. to about 380 ° C. and drum (D-11) through line 110. Is sent to and separated into vapor and liquid. The liquid exits line 112 and is heated in heat exchanger 113 to a temperature of about 225 ° C. to about 370 ° C. and then sent to countercurrent reactor R-2. The vapor from drum D-11 is also cooled by heat exchanger 115 and then sent to drum D-12 via line 114 for further separation of vapor and liquid components. The vapor containing hydrogen, hydrogen sulfide and light hydrocarbon components is added via line 120 to line 118 for delivery to drum D-13. The liquid is discharged and sent to stream 112 to be sent to reactor R-2 via line 122.
Countercurrent reactor (R-2) comprises two or more catalyst beds (B-1) (B-2). Reactor (R-2) comprises two reaction zones: a first zone in which countercurrent contact of hydrocarbons and hydrogen occurs, and a second zone in which forward, ie, cocurrent, contact of hydrocarbon and hydrogen occurs. As shown in FIG. 1, bed B-1 is in the first reaction zone and bed B-2 is in the second reaction zone. Hydrocarbon material is sent into reactor R-2 at a location between the first and second reaction zones. Each layer, or bed, comprises a hydrodesulfurization catalyst. Useful hydrodesulfurization catalysts include zeolites, noble metal catalysts, and similar materials as well as materials such as those described above (eg, Ni-Mo, Co-Mo, Ni-W on silica, alumina or silica-alumina carriers). do. The liquid material, or feed, from line 112 is sent into reactor R-2 between bed B-1 and bed B-2. Supplemental hydrogen (H) is provided at the bottom of the reactor (R-2). Reactor (R-2) is operated at a temperature of about 225 ° C. to about 450 ° C., a pressure of about 250 psig to about 1,500 psig, and a space velocity of about 0.6 LHSV to about 5.0 LHSV.
The major portion of hydrocarbon supplied to the reactor flows downward into the first reaction zone secured by bed B-1. Hydrogen entering the bottom of the reactor (R-2) flows upward through the catalyst bed (B-1) in the countercurrent flow as opposed to the downward flow of liquid. However, the hydrogen containing gas present as the effluent from the top of the first reaction zone, the bed B-1 in the government, is accompanied by a small portion of the hydrocarbons fed to the reactor. The steam and steam of the accompanying hydrocarbons will react with the gas containing hydrogen in the presence of the catalyst in bed (B-2). Since both the hydrocarbon moiety and the gas containing hydrogen flow upwards through the bed B-1, the contacting is carried out in a cocurrent manner. Positioning the catalyst bed (B-2) above the material inlet to receive effluent hydrogen containing gas from the first reaction zone is such that the reactor (R-2) does not encounter any hydrocarbons in the presence of a catalyst. Ensuring that it cannot pass through, thereby achieving the requirement of extremely low sulfur content. The top portion, ie top effluent 116, from the reactor R-2 is combined with the bottom liquid, and the total effluent of the reactor R-2 is transferred to the heat exchanger line 117. It cools and is sent to drum D-13 via line 118.
Liquid product P is separated and discharged from drum D-13 via line 126 and the vapor is removed via line 124. The methods and apparatus described herein will provide a useful product (P) as a diesel fuel component having a sulfur content of 50 ppm or less.
Steam government effluent (containing hydrogen, hydrogen sulfide and some hydrocarbon components) from drum D-13 is discharged through line 124 and then through air exchange unit 125 for cooling to an air cooling unit 130 is sent into drum D-14 for further separation of liquid and vapor. Liquid from drum D-14 is withdrawn from the bottom via line 134 and added to stream 126 to form a product stream P of petroleum fraction containing extremely low sulfur. Steam from drum D-14 (including hydrogen, hydrogen sulfide and some light hydrocarbons such as methane and ethane) is sent through line 132 to the bottom of absorber A, where steam is upwards The upflow is contacted in a countercurrent manner with the absorbent flowing downward to remove hydrogen sulfide from the vapor stream. More specifically, a lean amine absorbent (A-1) is provided at the top of the absorber 150, government. The amine absorbent is preferably an aqueous solution of an alkanolamine such as, for example, ethanolamine, diethanolamine, diisopropanolamine, methyldiethanolamine, tridiethanolamine.
Hydrogen-rich vapors (including some light hydrocarbon components) of the government effluent from absorber (A) are lined with a compressor (C-1) compressed to a pressure of about 400 psig to about 1,600 psig. 136). Stream 128 exiting compressor C-1 is a unit for heat exchange with stream 129 and stream 124 mixed with supplemental hydrogen stream H for sending to reactor R-2. It can be divided into stream 127 which is fed to stream F via 125.
Referring to FIG. 2, system 200 shows a modification of the hydrogen treatment scheme outlined at 201 in the diagram by merging countercurrent reaction scheme 202. Feed having the composition as described above, material F is combined with hydrogen (and light hydrocarbons) from stream 238 and then sent to reactor R-1, where the reaction conditions described above At least partial hydrodesulfurization is achieved. Effluent 210 from reactor R-1 is cooled in heat exchanger 211, ie, cooled and then sent to drum D-21 where liquid and vapor are separated. The vapor stream 226 from the drum D-21 passes through the heat exchanger 227 and the air cooler 230 and then to the drum D-24. Bottom liquid from drum D-21 is withdrawn as stream 212 and added to stream 214 from drum D-24, where additional pump 215 and heat exchanger 216 are thereafter. It is sent to the reactor (R-2) through. Exchange 216 adjusts the temperature of stream 214 to a temperature of about 200 ° C to about 450 ° C. As explained above, the material to reactor R-2 is provided between catalyst beds B-1 and B-2. The liquid flows downward through bed B-1 as opposed to the upward flow of hydrogen. The input supplemental hydrogen from the hydrogen source H is provided under the bed B-1 and flows upwards. In addition, the upward flow with hydrocarbon mist is treated in bed (B-2). Supercritical vapor containing hydrogen, hydrogen sulfide and hydrocarbon vapors is combined with bottom liquid from reactor (R-2) to form stream 218. The total effluent 218 from reactor R-2 is cooled in heat exchanger 219 and sent to settling drum D-22. The liquid from drum D-22 is withdrawn as product stream P. Vapor from drum D-22 is further cooled in heat exchanger 223 and sent to drum D-23 for further separation. Bottom liquid from drum D-23 is sent through stream 222 to product stream P of extremely low sulfur containing petroleum fraction. A government effluent vapor stream 224 is added to the vapor stream 226 from the drum D-21. As described above, stream 226 is cooled in heat exchanger 227 and then cooled in air cooler 230 and then sent to drum D-24. Bottom liquid of drum D-24 is sent to reactor R-2 via line 214. The government effluent vapor from the drum (D-24) containing hydrogen, hydrogen sulfide and light hydrocarbons is sent into an absorber (A), where a stream of amine H ₂ S absorbent flowing downwards as described above; Contact in a countercurrent manner. The H ₂ S-free vapor stream 232 of the government effluent mainly containing hydrogen, with some light hydrocarbons, is sent to the compressor (C-1) to compress from about 400 psig to about 1,600 psig. The discharge stream 234 of the compressor is heat exchanged for stream 226 in heat exchanger 227 with stream 236 added to make-up hydrogen stream H and introduced into reactor R-1. Divided into stream 238 which is added to material stream F for this purpose.
3, the system 300 is outlined to 301 and shows a modification of the hydrotreatment configuration by merging the countercurrent reaction configuration 302. In combination with a feed having the above-described composition, material F combined with stream 342 containing hydrogen and some light hydrocarbon compositions, and reacting the reactor (R-1) for at least a portion of the hydrodesulfurization under the given conditions. Is provided). Effluent 310 from reactor R-1 is cooled in heat exchanger 311 and sent to drum D-31 for separation of liquid and vapor. The liquid passes through an additional pump 314 and heat exchanger 315 and is sent to reactor R-2 via line 312. Exchange 315 regulates the temperature of stream 312 to a temperature of about 200 ° C to about 450 ° C. As described above, the material sent to the reactor R-2 is provided between the catalyst beds B-1 and (B-2). The liquid flows downward through bed B-1 as opposed to the upward flow of hydrogen. Supplemental hydrogen from the hydrogen source H is provided below the bed B-1 and flows upwards. The upward flow with hydrocarbon mist is further processed in bed B-2. Government effluent vapors containing hydrogen, hydrogen sulfide and hydrocarbon vapors are combined with the bottom liquid from reactor (R-2). Total effluent 318 from reactor R-2 is cooled in heat exchanger 319 and sent to settling drum D-32. The liquid in the drum D-32 exits the stream 322 to which bottom liquid from the drum D-33 forming the stream 328 is added. Stream 328 is added to stream 344 from drum D-34 to form product stream P. The vapor stream 320 of the drum D-32 is further cooled in the heat exchanger 321 and sent to the drum D-33 for further separation. The bottom liquid of drum D-33 is sent to stream 322 as described above via stream 324. Vapor stream 326 of the government effluent of drum D-33 is added to vapor stream 334 of drum D-34.
Steam stream 313 from drum D-31 is cooled by heat exchange in heat exchanger 325 before being sent to drum D-34 for separation of vapor and liquid, and air cooler 300 It is cooled by again. The bottom liquid stream 344 of the drum D-34 is combined with the liquid stream 382 of the drum D-32 to form a product stream P of petroleum fraction containing extremely low sulfur. The vapor stream of the upper government of the drum D-34 is combined with the vapor stream 326 of the drum D-33 and sent to the absorber A via line 334, as described above herein. Countercurrent contact with a stream of amine H ₂ S absorbent flowing downwards. The H ₂ S-free vapor stream 336 of the government effluent mainly containing hydrogen with some light hydrocarbons is sent to a compressor (C-1) to compress from about 400 psig to about 1,600 psig. The compressor output stream 338 is heat exchanged for stream 313 in stream 340 which is added to make-up hydrogen stream H and provided to reactor R-1. Divided into stream 342 which is added to the material stream F.
Referring to FIG. 4, system 400 is outlined at 401 and shows a modification of the hydrotreatment configuration by merging backflow reaction configuration 402. The feed having the composition described above, material (F), is combined with a stream 434 containing hydrogen and some light hydrocarbon constituents, and reacts with the reactor (R-1) for at least a portion of the hydrodesulfurization under the given conditions. Is provided). The effluent 410 of the reactor R-1 is sent to the drum D-41. The bottom liquid stream 414 from drum D-41 is cooled in heat exchanger 413. The vapor 412 of the upper government effluent is combined with the liquid stream 414 and then sent to reactor F-2. As explained above, the material sent to reactor R-2 is provided between catalyst beds B-1 and B-2. The liquid flows downward through bed B-1 for the upward flow of hydrogen. Supplemental hydrogen from the hydrogen source H is provided under the bed B-1 and flows upwards. The upstream with hydrocarbon mist is further processed in bed (B-2). The effluent stream 418 at the bottom of reactor R-2 is sent by chiller 417 through line 418 into drum D-42. Vapor 416 of the upper government effluent in reactor R-2 is added to stream 418 before cooling in chiller 417. The bottom liquid of drum D-42 is sent through stream 422 to become product stream P. The government effluent 420 of the drum D-42 is cooled by heat exchange in the heat exchanger 425 before being sent to the drum D-43 for separation of vapor and liquid, and the air cooler 430 Cools further). The bottom liquid stream 424 of the drum D-43 is combined with the liquid stream 422 of the drum D-42 to form a product stream P of petroleum fraction containing extremely low sulfur. The vapor stream of the upper government effluent of the drum D-43 is sent to the absorber A through line 426 and in countercurrent contact with the stream of amine H ₂ S absorbent flowing downward as described herein. The H ₂ S-free vapor stream 428 of the upper government effluent mainly containing hydrogen, with some light hydrocarbon components, is sent to a compressor (C-1) to compress from about 400 psig to about 1,600 psig. Lose. The compressor discharge stream is a stream 432 to which supplemental hydrogen stream (H) is added, heat exchanged to stream 420 in heat exchanger 425, and the material for providing into reactor R-1. Divided into stream 434 which is added to stream F.
Referring to FIG. 5, system 500 shows that co-current reactor R-1 is not used to pretreat the material by partial hydrotreating. Rather, only reactor (R-2) is used in the hydrogenation method. Material F is heated in heat exchanger 510 and heat exchanger 512 and then sent to heat exchanger 514 for further heating to a temperature of about 200 ° C. to about 450 ° C. The heated material is provided into reactor R-2 between beds B-1 and B-2 as described above. Hydrogen stream 529 is provided at the bottom of reactor R-2 and flows upwards as opposed to the downward flow of liquid petroleum distillate. As described above, the hydrocarbon compounds carried together due to the upward flow of the gas enter the bed (B-2) and undergo hydrotreatment, so that the entirety of the material (F) is discharged from the reactor (R-2) without the hydrogenation treatment. It doesn't work. The stream of top government effluent from reactor (R-2) is cooled in heat exchanger (510) by heat exchange of incoming material (F) and then sent to drum (D-51) for separation of liquid and vapor. . Bottom liquid from drum D-51 is sent through stream 520 to join stream 534, i.e., bottom liquid from drum D-53, to provide product stream P. A government effluent vapor stream 518 above the drum D-51 containing hydrogen, hydrogen sulfide and some light hydrocarbons is sent to the absorber A, where the upwardly flowing steam is lean flowing downwards. ) Contact with amine H ₂ S absorbent (A-1). H ₂ S-free vapor stream 522 of the upper government effluent from absorber (A) containing hydrogen and some light hydrocarbons is combined with make-up hydrogen from hydrogen source (H) And is sent to a compression apparatus C-2 / C-3 for compression. The stream 532 of the upper government effluent of the drum D-53 is combined with the effluent of the compressor C-2 to form the stream 523, which is cooled after being cooled in the heat exchanger 524. And to drum D-52 for further separation of steam. Bottom liquids from drum D-52 are sent through stream 528 to bottom stream 534 of drum D-53 to provide product P containing extremely low sulfur. Lose. The stream 529 of the upper government effluent of the drum D-52 is sent to the compressor C-3 for compression and then to the bottom of the reactor R-2. The overall compression between C-2 and C-3 is about 300 psig to about 1,600 psig.
With reference to FIG. 6, the product P containing extremely low sulfur can be further hydrogenated. For example, system 600 includes a reactor 610 for hydrodearomatization containing a bed of hydrogenated catalyst (B-3). The reactor is generally operated at a temperature of about 200 ° C. to about 400 ° C., a pressure of about 400 psig to about 1,600 psig, and a space velocity of about 0.3 LHSV to about 6 LHSV, preferably about 3.5 LHSV. Various hydrogenation processes have already been published and are well known, such as, for example, US Pat. No. 5,183,556, which is incorporated herein by reference. The catalyst in bed (B-3) is a noble or non-noble metal catalyst supplemented with silica, alumina, silica-alumina, zirconia, or other metal oxides. Hydrogen from the hydrogen source H is provided into the bottom of the reactor 610 and flows upward for the bottom stream of petroleum product fractionation. Vapor from the upper government effluent is removed through stream 602, and bottom effluent containing de-aromatic petroleum product is removed through stream 603.
Referring to FIG. 7, an alternative multiple layer countercurrent hydrogenation reactor (R-3) is shown. Reactor R-3 contains three spatially separated catalyst beds (B-1a), (B-1b) and (B-2). The material F is provided between the intermediate bed B-1b and the uppermost bed B-2. Hydrogen is provided via lines H-1 and H-2. The (H-1) input to the reactor (R-3) is located directly below the bed (B-1a) at the lowest position, and the (H-2) input to the reactor (R-3) is the bed (B). -1a) above and below the bed (B-2). Hydrogen flows upwards as opposed to the downward flow of petroleum product material F, and hydrogenation of the material F (e.g., hydrodesulfurization, hydrodenitrification) is brought into contact with hydrogen in countercurrent to the bed (B-1a) and ( In B-1b). As described above, some hydrocarbon components may be accompanied by an upward flow of hydrogen, which components are hydrogenated in bed B-2 so that all materials can be hydrogenated. The vapor stream V of the upper government effluent contains excess hydrogen, hydrogen sulfide and some light hydrocarbon components. The liquid effluent E taken from the bottom of the reactor comprises an petroleum effluent (eg diesel fuel) containing extremely low sulfur.
The following examples are presented in terms of the present invention.
Example
The feedstock was provided with a feedstock having a range of the following characteristics:
API specific gravity 27-40
Distillation Range ℃ (℉)
Initial boiling point 165-260 (330-500)
Final boiling point 280-440 (536-825)
Sulfur, wt% 0.01-0.05
Nitrogen, (total) wppm 5-100
The feedstock was treated in a hydrogenation system having a countercurrent reactor in accordance with the present invention. Reaction conditions included a hydrogenation catalyst comprising NiMo on a temperature of 346 ° C., a pressure of 750 psig, a space velocity of 1.6 LHSV and a silica carrier. The resulting product had an API specific gravity of 38.6, a sulfur content of 8 ppm by weight, and a nitrogen content of less than 1 ppm by weight.
While the above descriptions include many examples, these examples do not limit the scope of the present invention and should be construed merely as an example of a preferred embodiment of the present invention. For example, the first and second reaction zones may be placed in a single reactor vessel as well as other separate reactor vessels. Such techniques will allow those skilled in the art to envision many other possible variations within the spirit and scope of the invention as set forth in the claims herein.

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Claims (23)

In the hydrogenation method of petroleum fractionation, a) co-flowing the petroleum fraction in the reactor (R-1) of the first hydrogen stream and the first hydrogenation treatment unit under hydrogenation conditions to provide a partially treated first effluent containing a liquid component and a first vapor component Contacting process; b) cooling the first effluent in a first heat exchange step; c) removing the first vapor component from the first effluent cooled in the drum D-11 of one liquid vapor separation unit to provide a separation unit effluent containing only the liquid component; d) heating the separation unit effluent in a second heat exchange step to provide a heated liquid component; e) introducing the heated liquid component of step d) into a reactor (R-2) of a second hydroprocessing unit; f) combining the total treated government effluent and the treated bottom effluent to provide a combined treated effluent; and g) removing the second vapor component from the combined effluent of the second hydrotreatment unit to provide a product stream (P),   The main part of the heated liquid component of step d) is contacted with the second hydrogen stream in a countercurrent manner in the first reaction zone under hydrogenation conditions in the first catalyst bed (B-1) in the presence of the first hydrogenation catalyst, Providing a hydrogenated gaseous effluent leaving the first reaction zone at the government tip of the first reaction zone and a treated bottom effluent leaving the first reaction zone at the bottom tip of the first reaction zone; A small portion of the heated liquid component of step d) is contacted with the hydrogenous gaseous effluent in a co-current manner in a second reaction zone under hydrogenation conditions in the presence of a second hydrogenation catalyst, at the top end of the second reaction zone. Provide a treated government outflow outside the second reaction zone; The second hydrogenation treatment unit does not include a distillation process. 2. The first reaction zone of claim 1, wherein the second reaction zone of the reactor (R-2) of the second hydrogenation treatment unit is above the first reaction zone of the reactor (R-2) of the second hydrogenation treatment unit. Hydrogenation process of petroleum fractions, characterized in that located at intervals from. 3. The process of claim 2 wherein some hydrogen in the second hydrogen stream is introduced into the second hydroprocessing unit at a portion below the first reaction zone. 3. The lower second of claim 2, wherein a first reaction zone of said second hydroprocessing unit is positioned below and spaced below said first catalyst bed (B-1) and said first catalyst bed (B-1). A hydrogenation method of a petroleum fraction comprising a catalyst bed (B-2). The method of claim 4, wherein some hydrogen of the second hydrogen stream is introduced into the second hydrogenation processing unit under the lower second catalyst bed (B-2), and some hydrogen of the second hydrogen stream is introduced into the upper first catalyst bed (5). B-1) and the hydrogenation method of the petroleum fraction, characterized in that it is introduced into the second hydrogenation treatment unit between the lower second catalyst bed (B-2). The method of claim 1, wherein the temperature of the first and second reaction zones is below the boiling point of the liquid component under hydrogenation conditions. The method of claim 1, wherein the hydrogenation method is hydrodenitrification. 2. The process of claim 1 wherein the hydrogenation process is hydrodesulfurization and the product stream contains up to 50 ppm sulfur by weight. The method of claim 1, wherein the hydrogenation method is hydrogenation dearomatization. In the hydrogenation method of petroleum fractionation, a) co-flowing the petroleum fraction in the reactor (R-1) of the first hydrogen stream and the first hydrogenation treatment unit under hydrogenation conditions to provide a partially treated first effluent containing a liquid component and a first vapor component Contacting process; b) removing the first vapor component from the first effluent in the drum (D-21) of one liquid-vapor separation unit to provide a separation unit containing only the liquid component; c) cooling said separation unit liquid component and recombining said first steam component to a cooled separation unit liquid component to provide a combined liquid-vapor separation unit effluent; d) introducing the separation unit effluent of step c) into the reactor (R-2) of the second hydrogenation treatment unit; e) combining the total treated government effluent and the treated bottom effluent to provide a combined treated effluent; and f) removing the second vapor component from the combined treatment effluent of the second hydrotreatment unit to provide a product stream (P), The main part of the heated liquid component of step c) is contacted with the second hydrogen stream in a countercurrent manner in the first reaction zone under hydrogenation conditions of the first hydrogenation catalyst in the first catalyst bed (B-1), Providing a hydrogenated gaseous effluent leaving the first reaction zone at the top of the first reaction zone and a treated bottoms out of the first reaction zone at the bottom of the first reaction zone;  A small portion of the heated liquid component of step c) is contacted with the hydrogen-containing gaseous effluent in a co-current manner in the second reaction zone under hydrogenation conditions in the presence of a second hydrogenation catalyst, leading to the top of the second reaction zone. Provide treated government discharge outside of the second reaction zone in US;  The dehydrogenation unit does not include a distillation process. 2. The process of claim 1 wherein the petroleum fraction is an intermediate distillate having an initial boiling point in the range of 165 ° C to 260 ° C and a final boiling point in the range of 280 ° C to 440 ° C. According to claim 1, wherein the hydrogenation reaction conditions 200 ℃ to 450 ℃ temperature, 300 psig  A hydrogenation method of a petroleum fraction, comprising a pressure of ~ 1,500 psig and a space velocity of 0.4 to 20 LHSV. The first reaction zone according to claim 10, wherein the second reaction zone of the reaction device (R-2) of the second hydrogenation treatment unit is above the first reaction zone of the reaction device (R-2) of the second hydrogenation treatment unit. Hydrogenation process of petroleum fractions, characterized in that located at intervals from. The method of claim 1 wherein the first hydrogenation catalyst comprises one or more metals selected from the group consisting of cobalt, molybdenum, nickel and tungsten on the catalyst carrier. 15. The method of claim 14, wherein the catalyst carrier is an inorganic oxide selected from the group consisting of silica, alumina, silica-alumina, magnesia, zirconia, and titania. 14. The process of claim 13, wherein some of the hydrogen in the second hydrogen stream is introduced into the reactor (R-2) of the second hydroprocessing unit at a portion below the first reaction zone. The method of claim 10, wherein the temperature of the first and second reaction zones is below the boiling point of the liquid component under hydrogenation reaction conditions. The lower second catalyst bed according to claim 10, wherein the first reaction zone of the reactor (R-2) of the second hydrogenation treatment unit is positioned below the upper first catalyst bed (B-1) at intervals therefrom. A hydrogenation method of a petroleum fraction comprising (B-2). 19. The method of claim 18, wherein some of the hydrogen in the second hydrogen stream is introduced into the reactor (R-2) of the second hydrogenation treatment unit below the lower second catalyst bed (B-2), and a portion of the second hydrogen stream. Hydrogen is introduced into the reactor (R-2) of the second hydrogenation processing unit between the upper first catalyst bed (B-1) and the lower second catalyst bed (B-2). Way. In the hydrogenation method of petroleum fraction, a) introducing a petroleum fraction into the reactor (R-2) of the second hydrogenation treatment unit; b) cooling the treated bottoms effluent of the hydrotreatment unit; c) separating a first vapor component from the cooled bottom effluent to provide a treated product stream; d) cooling the treated effluent from the hydrotreatment unit; e) separating a second vapor component from said cooled and treated government effluent to provide a liquid bottom in combination with the product stream; f) washing the second vapor component to remove heteroatoms; g) adding hydrogen to said washed second vapor component; h) compressing the cleaned second steam component in a two stage compression system with intermediate separation and intermediate cooling of the liquid condensate to provide a compressed vapor stream; i) combining said liquid condensate with a product stream; and j) introducing a compressed vapor stream into said second hydroprocessing unit, In step a), the major part of the petroleum fraction is brought into contact with the stream of hydrogen in a countercurrent manner in the first reaction zone under the hydrogenation conditions of the presence of the first hydrogenation catalyst in the first catalyst bed, leading to the bottom tip of the first reaction zone. Provide a treated bottoms effluent leaving the first reaction zone at and a hydrogenous gaseous effluent leaving the first reaction zone at the government tip of the first reaction zone; A small portion of the petroleum fraction is brought into contact with the hydrogenous gaseous effluent in a co-current manner in a second reaction zone under hydrogenation conditions in the presence of a second hydrogenation catalyst, leaving the hydrogenation unit at the top of the hydrogenation unit. Providing an effluent; The hydrogenation method of the petroleum fraction, characterized in that the hydroprocessing unit does not include a distillation step. 21. The method of claim 20, wherein the temperature of the first and second reaction zones is below the boiling point of the liquid component under hydrogenation conditions. In the hydrogenation method of the hydrogen fraction, a) co-flowing the petroleum fraction in the reactor (R-1) of the first hydrogen stream and the first hydrogenation treatment unit under hydrogenation conditions to provide a partially treated first effluent containing a liquid component and a first vapor component Contacting process; b) cooling the first effluent in the first heat exchange step; c) removing the first vapor component from the first effluent cooled in one liquid vapor separation unit to provide a separation unit effluent containing only the liquid component; d) heating the separation unit effluent in a second heat exchange step to provide a heated liquid component; e) introducing the heated liquid component of step d) into the reactor (R-2) of the second hydrogenation treatment unit; f) combining the total treated government effluent and the treated bottom effluent to provide a combined treated effluent; and g) removing the second vapor component from the combined effluent of the second hydrotreatment unit to provide a product stream (P), The major part of the heated liquid component of step d) is contacted with the second hydrogen stream in a countercurrent manner in the first reaction zone under hydrogenation conditions in the presence of the first hydrogen catalyst in the first catalyst bed (B-1), Providing a hydrogenated gaseous effluent leaving the first reaction zone at the top of the first reaction zone and a treated bottom effluent leaving the first reaction zone at the bottom of the first reaction zone; A small portion of the heated liquid component of step d) is brought into contact with the hydrogenous gaseous effluent in a co-current manner in a second reaction zone under hydrogenation conditions in the presence of a second hydrogenation catalyst, at the top end of the second reaction zone. Provide a treated government effluent leaving the second reaction zone; And the second hydrogenation treatment unit is operated under reaction conditions for maintaining a liquid hydrocarbon phase. In the hydrogenation method of petroleum fraction, a) co-flowing the petroleum fraction in the reactor (R-1) of the first hydrogen stream and the first hydrogenation treatment unit under hydrogenation conditions to provide a partially treated first effluent containing a liquid component and a first vapor component Contacting process; b) cooling the first effluent in a first heat exchange step; c) removing the first vapor component from the first effluent cooled in the drum D-11 of one liquid vapor separation unit to provide a separation unit effluent containing only the liquid component; d) heating the separation unit effluent in a second heat exchange step to provide a heated liquid component; e) introducing the heated liquid component of step d) into the reactor (R-2) of the second hydrogenation treatment unit; f) combining the total treated government effluent and the treated bottom effluent to provide a combined treated effluent; and g) removing the second vapor component from the combined effluent of the second hydrotreatment unit to provide a product stream (P), The main part of the heated liquid component of step d) is contacted with the second hydrogen stream in a countercurrent manner in the first reaction zone under hydrogenation conditions in the presence of the first hydrogen catalyst in the first catalyst bed (B-1), Providing a hydrogenated gaseous effluent leaving the first reaction zone at the government front end of the first reaction zone and a treated bottom effluent leaving the first reaction zone at the bottom end of the first reaction zone; A small portion of the heated liquid component of step d) is completely entrained in the hydrogenous gaseous effluent and supported upwards, and hydrogen-containing gas in a co-current manner in a second reaction zone under hydrogenation conditions in the presence of a second hydrogenation catalyst. Contacting the effluent to provide a treated government effluent leaving the second reaction zone at the government tip of the second reaction zone.

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