CN115261067B - Residual oil hydrogenation method - Google Patents
Residual oil hydrogenation method Download PDFInfo
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- CN115261067B CN115261067B CN202110480780.4A CN202110480780A CN115261067B CN 115261067 B CN115261067 B CN 115261067B CN 202110480780 A CN202110480780 A CN 202110480780A CN 115261067 B CN115261067 B CN 115261067B
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- catalyst
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- residual oil
- hydrogenation
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- 238000005984 hydrogenation reaction Methods 0.000 title claims abstract description 93
- 238000000034 method Methods 0.000 title claims abstract description 72
- 239000003054 catalyst Substances 0.000 claims abstract description 142
- 238000006243 chemical reaction Methods 0.000 claims abstract description 68
- 238000004517 catalytic hydrocracking Methods 0.000 claims abstract description 40
- 239000002904 solvent Substances 0.000 claims abstract description 27
- 229910052717 sulfur Inorganic materials 0.000 claims abstract description 19
- YXFVVABEGXRONW-UHFFFAOYSA-N Toluene Chemical compound CC1=CC=CC=C1 YXFVVABEGXRONW-UHFFFAOYSA-N 0.000 claims abstract description 18
- 239000002994 raw material Substances 0.000 claims abstract description 18
- 239000000463 material Substances 0.000 claims abstract description 17
- 239000012071 phase Substances 0.000 claims abstract description 17
- 239000007791 liquid phase Substances 0.000 claims abstract description 16
- 239000010426 asphalt Substances 0.000 claims abstract description 14
- 239000002006 petroleum coke Substances 0.000 claims abstract description 11
- 238000000926 separation method Methods 0.000 claims abstract description 6
- 239000003921 oil Substances 0.000 claims description 126
- 229910052739 hydrogen Inorganic materials 0.000 claims description 29
- 239000001257 hydrogen Substances 0.000 claims description 29
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 claims description 26
- 229910052751 metal Inorganic materials 0.000 claims description 22
- 238000004939 coking Methods 0.000 claims description 21
- 230000003111 delayed effect Effects 0.000 claims description 19
- 239000002184 metal Substances 0.000 claims description 17
- 239000006185 dispersion Substances 0.000 claims description 16
- PXHVJJICTQNCMI-UHFFFAOYSA-N Nickel Chemical compound [Ni] PXHVJJICTQNCMI-UHFFFAOYSA-N 0.000 claims description 15
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims description 8
- GWEVSGVZZGPLCZ-UHFFFAOYSA-N Titan oxide Chemical compound O=[Ti]=O GWEVSGVZZGPLCZ-UHFFFAOYSA-N 0.000 claims description 8
- 239000002245 particle Substances 0.000 claims description 8
- 239000011148 porous material Substances 0.000 claims description 8
- 229910052721 tungsten Inorganic materials 0.000 claims description 8
- 229910052759 nickel Inorganic materials 0.000 claims description 7
- 230000036961 partial effect Effects 0.000 claims description 7
- ZOKXTWBITQBERF-UHFFFAOYSA-N Molybdenum Chemical compound [Mo] ZOKXTWBITQBERF-UHFFFAOYSA-N 0.000 claims description 6
- 229910017052 cobalt Inorganic materials 0.000 claims description 6
- 239000010941 cobalt Substances 0.000 claims description 6
- GUTLYIVDDKVIGB-UHFFFAOYSA-N cobalt atom Chemical compound [Co] GUTLYIVDDKVIGB-UHFFFAOYSA-N 0.000 claims description 6
- 229910052750 molybdenum Inorganic materials 0.000 claims description 6
- 239000011733 molybdenum Substances 0.000 claims description 6
- WFKWXMTUELFFGS-UHFFFAOYSA-N tungsten Chemical compound [W] WFKWXMTUELFFGS-UHFFFAOYSA-N 0.000 claims description 6
- 239000010937 tungsten Substances 0.000 claims description 6
- 229910052799 carbon Inorganic materials 0.000 claims description 5
- 229910052755 nonmetal Inorganic materials 0.000 claims description 5
- 238000012856 packing Methods 0.000 claims description 5
- PNEYBMLMFCGWSK-UHFFFAOYSA-N aluminium oxide Inorganic materials [O-2].[O-2].[O-2].[Al+3].[Al+3] PNEYBMLMFCGWSK-UHFFFAOYSA-N 0.000 claims description 4
- 239000000377 silicon dioxide Substances 0.000 claims description 4
- 239000011800 void material Substances 0.000 claims description 4
- 239000000295 fuel oil Substances 0.000 claims description 3
- 238000010438 heat treatment Methods 0.000 claims description 3
- ZOXJGFHDIHLPTG-UHFFFAOYSA-N Boron Chemical compound [B] ZOXJGFHDIHLPTG-UHFFFAOYSA-N 0.000 claims description 2
- ZAMOUSCENKQFHK-UHFFFAOYSA-N Chlorine atom Chemical compound [Cl] ZAMOUSCENKQFHK-UHFFFAOYSA-N 0.000 claims description 2
- PXGOKWXKJXAPGV-UHFFFAOYSA-N Fluorine Chemical compound FF PXGOKWXKJXAPGV-UHFFFAOYSA-N 0.000 claims description 2
- OAICVXFJPJFONN-UHFFFAOYSA-N Phosphorus Chemical compound [P] OAICVXFJPJFONN-UHFFFAOYSA-N 0.000 claims description 2
- QCWXUUIWCKQGHC-UHFFFAOYSA-N Zirconium Chemical compound [Zr] QCWXUUIWCKQGHC-UHFFFAOYSA-N 0.000 claims description 2
- YCOASTWZYJGKEK-UHFFFAOYSA-N [Co].[Ni].[W] Chemical compound [Co].[Ni].[W] YCOASTWZYJGKEK-UHFFFAOYSA-N 0.000 claims description 2
- 150000001335 aliphatic alkanes Chemical class 0.000 claims description 2
- 150000001336 alkenes Chemical class 0.000 claims description 2
- 229910052796 boron Inorganic materials 0.000 claims description 2
- 239000000460 chlorine Substances 0.000 claims description 2
- 229910052801 chlorine Inorganic materials 0.000 claims description 2
- 229910052804 chromium Inorganic materials 0.000 claims description 2
- WHDPTDWLEKQKKX-UHFFFAOYSA-N cobalt molybdenum Chemical compound [Co].[Co].[Mo] WHDPTDWLEKQKKX-UHFFFAOYSA-N 0.000 claims description 2
- 238000000605 extraction Methods 0.000 claims description 2
- 229910052731 fluorine Inorganic materials 0.000 claims description 2
- 239000011737 fluorine Substances 0.000 claims description 2
- 229910052732 germanium Inorganic materials 0.000 claims description 2
- GNPVGFCGXDBREM-UHFFFAOYSA-N germanium atom Chemical compound [Ge] GNPVGFCGXDBREM-UHFFFAOYSA-N 0.000 claims description 2
- DDTIGTPWGISMKL-UHFFFAOYSA-N molybdenum nickel Chemical compound [Ni].[Mo] DDTIGTPWGISMKL-UHFFFAOYSA-N 0.000 claims description 2
- MOWMLACGTDMJRV-UHFFFAOYSA-N nickel tungsten Chemical compound [Ni].[W] MOWMLACGTDMJRV-UHFFFAOYSA-N 0.000 claims description 2
- 229910052698 phosphorus Inorganic materials 0.000 claims description 2
- 239000011574 phosphorus Substances 0.000 claims description 2
- 229910052718 tin Inorganic materials 0.000 claims description 2
- 230000007704 transition Effects 0.000 claims description 2
- 229910052720 vanadium Inorganic materials 0.000 claims description 2
- 229910052726 zirconium Inorganic materials 0.000 claims description 2
- 239000011593 sulfur Substances 0.000 abstract description 17
- 239000000126 substance Substances 0.000 abstract description 4
- 238000004519 manufacturing process Methods 0.000 abstract description 3
- 238000012545 processing Methods 0.000 abstract description 3
- 238000005516 engineering process Methods 0.000 description 13
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 10
- 239000000047 product Substances 0.000 description 10
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 description 9
- 238000009826 distribution Methods 0.000 description 8
- 239000007788 liquid Substances 0.000 description 7
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 6
- 230000000052 comparative effect Effects 0.000 description 6
- 239000007789 gas Substances 0.000 description 6
- 239000002002 slurry Substances 0.000 description 6
- 238000009835 boiling Methods 0.000 description 5
- 238000007670 refining Methods 0.000 description 5
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 description 4
- 239000010779 crude oil Substances 0.000 description 4
- 238000002360 preparation method Methods 0.000 description 4
- 239000005995 Aluminium silicate Substances 0.000 description 3
- 235000012211 aluminium silicate Nutrition 0.000 description 3
- 238000004523 catalytic cracking Methods 0.000 description 3
- 239000010724 circulating oil Substances 0.000 description 3
- 150000002431 hydrogen Chemical class 0.000 description 3
- 239000012535 impurity Substances 0.000 description 3
- NLYAJNPCOHFWQQ-UHFFFAOYSA-N kaolin Chemical compound O.O.O=[Al]O[Si](=O)O[Si](=O)O[Al]=O NLYAJNPCOHFWQQ-UHFFFAOYSA-N 0.000 description 3
- 229910052757 nitrogen Inorganic materials 0.000 description 3
- 230000009466 transformation Effects 0.000 description 3
- GRYLNZFGIOXLOG-UHFFFAOYSA-N Nitric acid Chemical compound O[N+]([O-])=O GRYLNZFGIOXLOG-UHFFFAOYSA-N 0.000 description 2
- 238000010306 acid treatment Methods 0.000 description 2
- APUPEJJSWDHEBO-UHFFFAOYSA-P ammonium molybdate Chemical compound [NH4+].[NH4+].[O-][Mo]([O-])(=O)=O APUPEJJSWDHEBO-UHFFFAOYSA-P 0.000 description 2
- 229940010552 ammonium molybdate Drugs 0.000 description 2
- 235000018660 ammonium molybdate Nutrition 0.000 description 2
- 239000011609 ammonium molybdate Substances 0.000 description 2
- 230000000903 blocking effect Effects 0.000 description 2
- 239000003795 chemical substances by application Substances 0.000 description 2
- 239000000571 coke Substances 0.000 description 2
- 239000002283 diesel fuel Substances 0.000 description 2
- 238000001035 drying Methods 0.000 description 2
- 238000001914 filtration Methods 0.000 description 2
- 238000005194 fractionation Methods 0.000 description 2
- 239000003502 gasoline Substances 0.000 description 2
- 238000009775 high-speed stirring Methods 0.000 description 2
- 238000002156 mixing Methods 0.000 description 2
- 229910017604 nitric acid Inorganic materials 0.000 description 2
- 238000003756 stirring Methods 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- PFRUBEOIWWEFOL-UHFFFAOYSA-N [N].[S] Chemical compound [N].[S] PFRUBEOIWWEFOL-UHFFFAOYSA-N 0.000 description 1
- 239000000654 additive Substances 0.000 description 1
- 230000000996 additive effect Effects 0.000 description 1
- 150000004945 aromatic hydrocarbons Chemical class 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 239000012018 catalyst precursor Substances 0.000 description 1
- 239000013064 chemical raw material Substances 0.000 description 1
- 239000007809 chemical reaction catalyst Substances 0.000 description 1
- 239000007795 chemical reaction product Substances 0.000 description 1
- 239000000084 colloidal system Substances 0.000 description 1
- 238000005336 cracking Methods 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 230000008021 deposition Effects 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 238000004821 distillation Methods 0.000 description 1
- 238000005265 energy consumption Methods 0.000 description 1
- 238000001125 extrusion Methods 0.000 description 1
- 230000002349 favourable effect Effects 0.000 description 1
- 238000011049 filling Methods 0.000 description 1
- 238000009776 industrial production Methods 0.000 description 1
- 230000002401 inhibitory effect Effects 0.000 description 1
- 230000000670 limiting effect Effects 0.000 description 1
- 239000003915 liquefied petroleum gas Substances 0.000 description 1
- 238000011068 loading method Methods 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 230000010355 oscillation Effects 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 238000005191 phase separation Methods 0.000 description 1
- 238000006116 polymerization reaction Methods 0.000 description 1
- 238000003672 processing method Methods 0.000 description 1
- 238000004064 recycling Methods 0.000 description 1
- 230000002829 reductive effect Effects 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 101150110872 ric-3 gene Proteins 0.000 description 1
- 229930195734 saturated hydrocarbon Natural products 0.000 description 1
- 239000013049 sediment Substances 0.000 description 1
- 238000004904 shortening Methods 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- LEONUFNNVUYDNQ-UHFFFAOYSA-N vanadium atom Chemical compound [V] LEONUFNNVUYDNQ-UHFFFAOYSA-N 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G67/00—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one process for refining in the absence of hydrogen only
- C10G67/02—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one process for refining in the absence of hydrogen only plural serial stages only
- C10G67/04—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one process for refining in the absence of hydrogen only plural serial stages only including solvent extraction as the refining step in the absence of hydrogen
- C10G67/0454—Solvent desasphalting
- C10G67/049—The hydrotreatment being a hydrocracking
Abstract
The invention relates to the field of residual oil processing, and discloses a residual oil hydrogenation method, which comprises the following steps: introducing a residual oil raw material, a dispersed catalyst and deasphalted oil into a fixed bed residual oil hydrogenation reaction zone filled with a residual oil hydrotreating catalyst for hydrogenation reaction, and introducing hydrogenated oil obtained by hydrogenation reaction into a hot high-pressure separator for separation to obtain a gas-phase stream and a liquid-phase stream, wherein the content of toluene insoluble matters in the hydrogenated oil is not more than 0.1wt%, and the dosage of the dispersed catalyst is 0.01-2.0wt% based on the total weight of the residual oil raw material and the deasphalted oil; solvent deasphalting the liquid phase material flow to obtain deasphalted asphalt and deasphalted oil recycled to hydrogenation reaction; and carrying out hydrocracking reaction on the gas-phase material flow to obtain heavy naphtha. The residual oil hydrogenation method of the invention ensures the stability of hydrogenated oil, greatly improves the conversion rate of residual oil, and can realize the production of chemical raw materials and low-sulfur petroleum coke.
Description
Technical Field
The invention relates to the field of residual oil processing, in particular to a residual oil hydrogenation method.
Background
Under the conditions of increasing the downstream pressure of world economic development, slowing down the increase of petroleum demand and increasing the fluctuation of oil price oscillation, the oil refining industry is faced with huge transformation pressure. At present, the oil refining productivity of China is obviously excessive, but the increase of the demands of chemical raw materials and low-sulfur petroleum coke still has a large space, and oil refining enterprises have to accelerate the transformation from mass production of finished oil to mass production of chemical raw materials and low-sulfur petroleum coke.
40-60% of crude oil is residual oil, oil refining enterprises urgently need high-efficiency conversion technology of residual oil, and residual oil hydrogenation technology is an important technical means of residual oil conversion and plays an important role in modern oil refining industry. The residuum hydrogenation technology is mainly divided into fixed bed, ebullated bed and slurry bed residuum hydrogenation technology according to the different reactor forms.
The fixed bed residuum hydrogenation technology was developed based on distillate oil hydrogenation technology in the 60 th century. The residual oil is boosted to the pressure of the reaction system by a pump, mixed with the new hydrogen and the circulating hydrogen, heated by a heating furnace and then enters the reactor. The catalyst in the reactor is fixed, and cold hydrogen is pumped between catalyst beds to control the reaction temperature.
The boiling bed residuum hydrogenation technology was developed successfully in the last 60 th century, and the reactor is a three-phase fluidized bed system in which gas, liquid and catalyst particles are back mixed. Hydrogen and raw oil enter from the bottom of the reactor, are mixed with circulating oil, and pass through a bubble cap distribution plate to lift the catalyst upwards so as to expand and keep the catalyst bed in a fluidized state. The boiling catalyst bed height can be controlled by the recycle oil flow.
Slurry bed residuum hydrogenation technology is a gas/liquid/solid three-phase reaction process, and the catalyst is driven by moving gas/liquid to be in fluidized state. The catalyst used in the technology has small particle size, large outer surface, high catalyst particle number in unit volume of liquid medium and small catalyst particle spacing, and is favorable for inhibiting the polymerization reaction of liquid.
At present, the fixed bed residual oil hydrogenation technology is the residual oil hydrogenation method with the widest application range and the most mature process, and has simple process and equipment, easy operation and lower investment cost of the device. The liquid in the fixed bed reactor approximates plug flow, no back mixing exists, and the efficiency of hydrodesulfurization, nitrogen and other impurities is high. However, the conversion rate of the fixed bed residuum hydrogenation technology is lower, and usually only 10-20% of hydrogenated residuum is required to be cracked by a subsequent catalytic cracking device, so that high-value products such as LPG, gasoline, diesel oil and the like can be obtained.
The boiling bed and slurry bed residual oil hydrogenation technology has the advantages that the catalyst can be replaced on line, the reaction temperature is high, higher residual oil conversion rate can be realized, but serious backmixing phenomenon exists in the reactor, the removal rate of sulfur, nitrogen and other impurities is low, the stability of hydrogenated oil is reduced under the condition of high conversion rate, the coking and blocking of a subsequent system are easy to cause, and the long-period safe operation of the device is seriously influenced. In the industrial production process, in order to avoid coking and blocking, the boiling bed and slurry bed residual oil hydrogenation devices are designed with very complex heat exchange and separation systems, so that the investment cost and the operation difficulty of the devices are increased.
In the conversion of resid, the maximum conversion level is limited by the stability of the resulting resid. The residuum conversion process changes the chemistry of oils and asphaltenes, resulting in a gradual decrease in stability as the severity increases. Beyond a certain limit, the degree of phase separation (i.e., deposition) of asphaltenes in the feed increases and thus initiates the coke formation process. The generated coke can be separated out in a subsequent heat exchanger, a fractionating tower and the like, and the long-period safe operation of the device is seriously affected.
Research shows that the stability of the hydrogenated oil of the residual oil is closely related to the conversion rate of the residual oil, toluene insoluble matters are adopted to represent the stability of the hydrogenated oil, and the higher the toluene insoluble matters are, the easier the hydrogenated oil is to generate sediment and the less stable the hydrogenated oil is.
US4427535a discloses a process for achieving high conversion of heavy oils by hydrocracking. The method adopts boiling bed technology to process inferior heavy product containing 10-28wt% asphaltene and 12-35wt% carbon residueCrude oil, such as Canadian cold lake crude oil and Lloydminster crude oil, is reacted at a reaction temperature of 404-446 ℃ and a reaction pressure of 14.2-21.1MPa, and a volume space velocity of 0.25-5.0h -1 Under the conditions of 65-80% conversion can be achieved.
CN101098949a discloses a process for the conversion of heavy feedstocks such as heavy crude oils and distillation residues. The method comprises the steps of feeding residual oil into a deasphalting section, mixing the deasphalted oil with a proper hydrogenation catalyst precursor, and feeding the mixture into a hydrotreating reactor. The stream containing the hydrogenation reaction product and catalyst in the dispersed phase is passed to a fractionation column where at least a portion of the distilled residuum and liquid from a flash unit are recycled. The process is capable of achieving conversions in excess of 95%.
Disclosure of Invention
The invention aims to overcome the defect of low conversion rate of a fixed bed residual oil hydrogenation method in the prior art, and is expected to utilize the existing fixed bed residual oil hydrogenation device to greatly improve the conversion rate of residual oil while ensuring the stability of hydrogenated oil and long device operation period, so as to produce chemical raw materials and low-sulfur petroleum coke.
In order to achieve the above object, the present invention provides a residuum processing method comprising:
(1) Introducing a residual oil raw material, a dispersion type catalyst and deasphalted oil into a fixed bed residual oil hydrogenation reaction zone filled with a residual oil hydrotreating catalyst in the presence of hydrogen to carry out hydrogenation reaction to obtain hydrogenation generated oil, wherein the content of toluene insoluble matters in the hydrogenation generated oil is not more than 0.1wt%, and the use amount of the dispersion type catalyst is 0.01-2.0wt% based on the total weight of the residual oil raw material and the deasphalted oil;
(2) Introducing the hydrogenated oil into a hot high-pressure separator for separation to obtain a gas-phase material flow and a liquid-phase material flow containing hydrogenated residual oil;
(3) Subjecting the liquid phase stream to solvent deasphalting to obtain deasphalted asphalt and deasphalted oil recycled back to the fixed bed residuum hydrogenation reaction zone of step (1) for the hydrogenation reaction; and
introducing the gas-phase material flow into a hydrocracking reaction zone filled with a hydrocracking catalyst to carry out hydrocracking reaction, and obtaining heavy naphtha.
The technical scheme of the invention has the following advantages:
1. the invention has the advantages of both fixed bed and movable bed (ebullated bed and slurry bed) residuum hydrogenation apparatus, and by adding a specific amount of dispersion catalyst into the feed, the high sulfur nitrogen impurity removal rate of the fixed bed residuum hydrogenation apparatus is maintained, the high conversion rate of residuum is realized, and the long-period safe operation of the apparatus can be realized.
2. The invention realizes the high-efficiency utilization of hydrogen and carbon in the residual oil, wherein the hydrogen in the residual oil is mainly used for producing heavy naphtha with high hydrogen content, and the carbon is mainly used for producing low-sulfur petroleum coke.
3. The product produced by the method has flexible and reasonable structure, and can flexibly adjust the residual oil conversion rate of the fixed bed residual oil hydrogenation device by adjusting the adding proportion of the dispersed catalyst and controlling the hydrogenation causticity scale of the hydrogenation device according to different demands of the market.
4. The invention fully utilizes the heat and pressure of the hot high-pressure separator, realizes the further cracking of the hydrogenated diesel oil and the hydrogenated wax oil by adding the hydrocracking reactor after the fixed bed residual oil hydrogenation device, and obtains the heavy naphtha as the chemical raw material, and the whole processing flow is simple, the energy consumption is low and the cost is low.
Drawings
FIG. 1 is a process flow diagram of a preferred embodiment of the method of the present invention.
Description of the reference numerals
1. Residuum raw material 2, dispersed catalyst
3. Fixed bed residuum hydrogenation reaction zone 4, hydrogenation generated oil
5. Hot high pressure separator 6, gas phase stream
7. Hydrocracking reaction zone 8, heavy naphtha
9. Liquid phase material flow 10 and solvent deasphalting device
11. Deoiling asphalt 12, deasphalting oil
13. Delayed coking treatment device 14 and low sulfur petroleum coke
Detailed Description
The endpoints and any values of the ranges disclosed herein are not limited to the precise range or value, and are understood to encompass values approaching those ranges or values. For numerical ranges, one or more new numerical ranges may be found between the endpoints of each range, between the endpoint of each range and the individual point value, and between the individual point value, in combination with each other, and are to be considered as specifically disclosed herein.
In the present invention, the pressure is expressed in the form of hydrogen partial pressure, and is gauge pressure, unless otherwise specified.
In the present invention, the particle size of the catalyst refers to the maximum distance between two different points on the cross section of the particle, unless otherwise specified.
As previously described, the present invention provides a process for hydrogenating residuum comprising:
(1) Introducing a residual oil raw material, a dispersion type catalyst and deasphalted oil into a fixed bed residual oil hydrogenation reaction zone filled with a residual oil hydrotreating catalyst in the presence of hydrogen to carry out hydrogenation reaction to obtain hydrogenation generated oil, wherein the content of toluene insoluble matters in the hydrogenation generated oil is not more than 0.1wt%, and the use amount of the dispersion type catalyst is 0.01-2.0wt% based on the total weight of the residual oil raw material and the deasphalted oil;
(2) Introducing the hydrogenated oil into a hot high-pressure separator for separation to obtain a gas-phase material flow and a liquid-phase material flow containing hydrogenated residual oil;
(3) Subjecting the liquid phase stream to solvent deasphalting to obtain deasphalted asphalt and deasphalted oil recycled back to the fixed bed residuum hydrogenation reaction zone of step (1) for the hydrogenation reaction; and
introducing the gas-phase material flow into a hydrocracking reaction zone filled with a hydrocracking catalyst to carry out hydrocracking reaction, and obtaining heavy naphtha.
Preferably, the dispersed catalyst is used in an amount of 0.02 to 1.5wt% based on the total weight of the residuum feedstock and the deasphalted oil. The inventors have found that with this preferred embodiment, the conversion of residuum can be made higher without shortening the run time.
Preferably, in step (1), the dispersed catalyst has an average particle diameter of 0.1 μm to 25 μm.
According to a preferred embodiment, in step (1), the dispersed catalyst is a particulate catalyst comprising a metallic element selected from at least one of group IVA and group VIA nonmetallic elements, and a nonmetallic element selected from at least one of group VB, group VIB, group IVA and group VIII metallic elements; the content of the metal element in terms of oxide is 5-20wt% based on the total weight of the dispersion catalyst, and the content of the nonmetallic element is 80-95wt%.
Particularly preferably, the metal element is selected from at least one of Cr, V, mo, W, ni, fe, co and Sn, and the non-metal element is selected from at least one of C, si, and S.
In the present invention, the dispersed catalyst may be selected from commercial catalysts known in the art or prepared using known methods of the prior art, and the specific operations exemplified hereinafter of the present invention should not be construed as limiting the invention.
According to a preferred embodiment, the conditions of the fixed bed residuum hydrogenation reaction zone are controlled such that the conversion of the residuum feedstock is no less than 30%.
Preferably, in step (1), the conditions of the fixed bed residuum hydrogenation reaction zone are at least: the hydrogen partial pressure is 1.0-22.0MPa, the reaction temperature is 330-470 ℃ and the volume space velocity is 0.1-3.0h -1 The volume ratio of hydrogen oil is 350-2000.
More preferably, the fixed bed residuum hydrogenation reaction zone conditions are at least: the hydrogen partial pressure is 8.0-21.0Mpa, the reaction temperature is 360-460 ℃, and the volume space velocity is 0.2-2.5h -1 The volume ratio of hydrogen to oil is 400-1500. The inventors have found that with this preferred embodiment, higher residuum conversion can be achieved.
Preferably, in step (1), the bulk density of the residuum hydrotreating catalyst is in the range of 300-900kg/m 3 The average pore diameter is 5-20nm, the pore volume is not less than 0.45ml/g, and the specific surface area is not less than 90m 2 /g。
According to a particularly preferred embodiment, in step (1), the residuum hydrotreating catalyst is selected from at least one of hydrodemetallization catalysts, hydro-guard catalysts, transition catalysts, hydrodesulphurisation denitrification catalysts.
According to another particularly preferred embodiment, the fixed bed residuum hydrogenation reaction zone is charged with the hydroprotection catalyst, the hydrodemetallization catalyst and the hydrodesulphurisation denitrification catalyst sequentially in the direction of flow.
Preferably, the loading volume ratio of the hydrogenation protecting catalyst, the hydrodemetallization catalyst and the hydrodesulphurisation denitrification catalyst is 1: (2-10): (5-12).
Preferably, in the step (1), the residuum hydrotreating catalyst contains a support and an active metal element supported on the support, the support being selected from at least one of alumina, silica, and titania, the active metal element being selected from group vib and/or group viii metal elements.
More preferably, in the residuum hydrotreating catalyst, the active metal element is selected from at least one of a combination of nickel-tungsten, a combination of nickel-tungsten-cobalt, a combination of nickel-molybdenum, and a combination of cobalt-molybdenum.
In particular, the content of the active metal element in terms of oxide is 0.05 to 25wt%, preferably 1 to 20wt%, based on the total weight of the residuum hydrotreating catalyst.
Preferably, the residuum hydrotreating catalyst further contains at least one additive element selected from the group consisting of boron, germanium, zirconium, phosphorus, chlorine, and fluorine.
More preferably, the total content of the auxiliary elements in terms of elements in the residuum hydrotreating catalyst is from 0.01 to 10wt%.
In the present invention, the resid hydrotreating catalyst may be selected from commercial catalysts known in the art or prepared using known methods of the prior art, and illustratively, the resid hydrotreating catalyst may employ RG-series, RDM-series, RMS-series, RCS-series, and RSN-series commercial catalysts developed by the institute of petrochemical chemistry and petrochemical science.
According to a particularly preferred embodiment, the residuum hydrotreating catalyst is selected from at least one of the grades RG-30B, RDM-202 and RCS-31 produced by the Kaolin catalyst plant of China petrochemical catalyst division.
Preferably, in step (1), the fixed bed residuum hydrogenation reaction zone contains at least 2 fixed bed reactors in series in sequence.
Preferably, the fixed bed residual oil hydrogenation reaction zone comprises 2-6 fixed bed reactors which are sequentially connected in series.
The temperature of the fixed bed residuum hydrogenation reaction zone is, unless otherwise specified, the average temperature of the individual fixed bed reactor beds.
Preferably, in step (1), the residuum hydroprocessing catalyst has a bed void fraction, e, of greater than 0.40, the catalyst has a bed void fraction, e= (bed volume-bed packing volume)/bed volume, and the units of the bed volume and the bed packing volume are the same (e.g., both are mL), the bed packing being the residuum hydroprocessing catalyst.
Preferably, in step (1), the residuum feedstock is selected from at least one of atmospheric residuum, vacuum residuum, heavy oil.
Preferably, the residuum feedstock has a density (20 ℃) of greater than 950kg/m 3 。
According to a particularly preferred embodimentIn an embodiment, the conditions of the hot high pressure separator are controlled such that the density (20 ℃) of the gas phase stream is 500-1000kg/m 3 A hydrogen content of not less than 5wt%; the density (20 ℃) of the liquid-phase stream is 800-1200kg/m 3 The sulfur content is less than 5wt% and the carbon residue content is less than 45wt%.
Preferably, in step (2), the conditions of the hot high pressure separator at least satisfy: the temperature is 330-450 ℃, and the pressure is 5-22Mpa.
According to a particularly preferred embodiment, the conditions of the solvent deasphalting treatment are controlled so that the sulfur content of the deasphalted bitumen is less than 2 wt.%, the carbon residue value of the deasphalted oil is less than 50 wt.%, and the sulfur content is less than 3 wt.%.
According to a preferred embodiment, in step (3), the conditions of the solvent deasphalting treatment at least satisfy: the extraction temperature is 100-300 ℃, the pressure is 0.5-5MPa, and the volume ratio of the catalyst to the oil is (5-10): 1, wherein the volume ratio of the solvent to the liquid phase material flow is the volume ratio of the solvent to the liquid phase material flow.
More preferably, the solvent involved in the solvent deasphalting treatment is selected from C 5 -C 8 Alkane, C 5 -C 8 At least one of olefins, condensate and naphtha.
The specific method of operation of the solvent deasphalting treatment is not particularly limited in the present invention and may be any known method of operation in the art.
According to another preferred embodiment, in step (3), the conditions of the hydrocracking reaction zone at least satisfy: the hydrogen partial pressure is 5.0-22.0MPa, the reaction temperature is 300-450 ℃, and the volume space velocity is 0.1-2.0h -1 The volume ratio of hydrogen oil is 350-2000.
Preferably, the hydrocracking catalyst has a bulk density of 500-1200g/cm 3 The average pore diameter is 5-20nm, the pore volume is not less than 0.2ml/g, and the specific surface area is not less than 190m 2 /g。
More preferably, the hydrocracking catalyst contains a carrier and an active metal element supported on the carrier, the carrier is selected from at least one of alumina, silica and titania, and the active metal element is selected from at least one of nickel, cobalt, molybdenum and tungsten.
Particularly preferably, in the hydrocracking catalyst, the content of nickel and/or cobalt in terms of oxide is 0-30wt%, the content of molybdenum and/or tungsten in terms of oxide is 0-35wt%, and the sum of the contents of nickel, cobalt, molybdenum and tungsten in terms of oxide is more than 0, based on the total weight of the hydrocracking catalyst.
In the present invention, the hydrocracking reaction zone may employ a known hydrocracking system, and may illustratively include a reactor, a fractionation system, employing a combination of fixed bed reactors and/or slurry bed reactors.
Preferably, the shape of the residuum hydrotreating catalyst or the hydrocracking catalyst in the present invention is Raschig ring or butterfly extrusion.
The subsequent treatment of the deoiled asphalt is not particularly required and may be carried out by those skilled in the art using operations known in the art, for example, the deoiled asphalt of the present invention may be introduced into a delayed coking treatment apparatus for delayed coking reaction, etc.
According to a particularly preferred embodiment, the process further comprises subjecting said deoiled asphalt to a delayed coking treatment, obtaining petroleum coke.
Preferably, the conditions of the delayed coking process at least satisfy: the outlet temperature of the heating furnace is 450-600 ℃, the pressure is 0.1-0.5MPa, and the circulation ratio is 0.1-1, wherein the circulation ratio is the ratio of the circulating oil mass to the fresh oil mass (the circulating oil can be coked wax oil generally).
The following provides a process flow for a preferred embodiment of the fixed bed residuum hydrogenation process of this invention in connection with FIG. 1:
(1) Introducing a residual oil raw material 1, a dispersed catalyst 2 and deasphalted oil 12 into a fixed bed residual oil hydrogenation reaction zone 3 to carry out hydrogenation reaction in the presence of hydrogen to obtain hydrogenation generated oil 4;
(2) Introducing the hydrogenation generated oil 4 into a hot high-pressure separator 5 for separation to obtain a gas-phase stream 6 and a liquid-phase stream 9;
(3) Introducing the liquid-phase material flow 9 into a solvent deasphalting device 10 for solvent deasphalting treatment to obtain deasphalted asphalt 11 and deasphalted oil 12 which is recycled to the fixed bed residual oil hydrogenation reaction zone in the step (1) for hydrogenation reaction, and introducing the deasphalted asphalt 11 into a delayed coking treatment device 13 for delayed coking treatment to obtain low-sulfur petroleum coke 14; and introducing the gas phase stream 6 into a hydrocracking reaction zone 7 for hydrocracking reaction to obtain heavy naphtha 8.
The invention will be described in detail below by way of examples. In the following examples, various raw materials used without particular description are commercially available.
In the following examples, without corresponding description:
the hydrogenation reaction is carried out in a fixed bed residual oil hydrotreating medium-sized device;
the solvent deasphalting treatment is carried out in a solvent deasphalting treatment device;
the hydrocracking reaction is carried out in a medium-sized apparatus;
the delayed coking process is performed in a delayed coking process unit;
the residuum feedstock properties are shown in table 1;
the amount of the dispersed catalyst is based on the total weight of the residuum feedstock and the deasphalted oil;
in a fixed bed residuum hydrotreatment reaction zone, a catalyst A, a catalyst B and a catalyst C are sequentially filled along the flow direction, wherein the filling volume ratio of the catalyst A to the catalyst B to the catalyst C is 9:41:50;
the catalyst A, the catalyst B and the catalyst C are produced by a kaolin catalyst factory of China petrochemical catalyst division company, and the types and the properties of the catalyst A, the catalyst B and the catalyst C are shown in a table 2;
wherein the catalyst A is a hydrogenation protection catalyst, the catalyst B is a hydrodemetallization catalyst, and the catalyst C is a hydrodesulphurization denitrification catalyst;
the types of the hydrocracking catalysts are RIC-3, and are produced by a kaolin catalyst factory of China petrochemical catalyst division company, and the specific properties are shown in Table 2.
The dispersed catalyst FS-1 and the dispersed catalyst FS-2 in the following examples were prepared by the method described in preparation example 1 or preparation example 2;
preparation example 1
The dispersed catalyst FS-1 was prepared by the following method:
5.89g of ammonium molybdate ((NH) 4 ) 6 Mo 7 O 24 ·4H 2 After stirring evenly O) and 300mL of water, 83g of activated carbon subjected to acid treatment (hydrochloric acid with concentration of 2mol/L and nitric acid with concentration of 2mol/L are sequentially used) and 7.2g of vulcanizing agent (sublimated sulfur) are added, vulcanizing is carried out for 60min under the conditions of 300 ℃ and 7.0MPa (initial hydrogen pressure) and high-speed stirring (300 rpm), and the dispersed residual oil hydrogenation catalyst FS-1 is obtained after filtering and drying, wherein the specific properties are shown in Table 2.
Preparation example 2
The dispersed catalyst FS-2 was prepared by the following method:
6.79g of ammonium molybdate ((NH) 4 ) 6 Mo 7 O 24 ·4H 2 After stirring evenly O) and 300mL of water, 90g of activated carbon subjected to acid treatment (hydrochloric acid with concentration of 2mol/L and nitric acid with concentration of 2mol/L are sequentially treated), 8.5g of vulcanizing agent (sublimated sulfur) are added, vulcanizing is carried out for 80min under the conditions of 350 ℃, 9.0MPa (initial hydrogen pressure) and high-speed stirring (300 rpm), and the dispersed residual oil hydrogenation catalyst FS-2 is obtained after filtering and drying, wherein the specific properties are shown in Table 2.
Table 1: residuum feedstock properties
| Project | Residuum A | Residuum B |
| Density (20 ℃ C.) kg/m 3 | 985.0 | 1012.5 |
| Kinematic viscosity (100 ℃ C.) mm 2 /s | 300 | 3000 |
| Carbon residue content, wt% | 12.3 | 22.4 |
| Nitrogen content, wt% | 0.26 | 0.40 |
| Sulfur content, wt% | 4.1 | 5.5 |
| The content of the four components is wt% | ||
| Saturated hydrocarbons | 20.5 | 7.6 |
| Aromatic hydrocarbons | 50.1 | 54.4 |
| Colloid | 23.6 | 23.4 |
| Asphaltenes (C) 7 Insoluble matter | 5.8 | 11.6 |
| Metal content, ppm | ||
| Nickel (Ni) | 85 | 110 |
| Vanadium (V) | 8 | 256 |
Table 2: residuum hydroprocessing catalysts and types and properties of dispersible catalysts
Example 1
The present embodiment is performed by using the process flow shown in fig. 1, specifically:
(1) Introducing the residual oil A, the dispersed catalyst FS-1 and the deasphalted oil from the step (2) into a fixed bed residual oil hydrogenation reaction zone filled with a residual oil hydrotreating catalyst to carry out hydrogenation reaction in the presence of hydrogen, and separating hydrogenated oil obtained after the hydrogenation reaction in a hot high-pressure separator to obtain a gas-phase stream and a liquid-phase stream; wherein the dispersed catalyst is used in an amount of 0.03wt% based on the total weight of the residuum feedstock and the deasphalted oil;
(2) Carrying out solvent deasphalting treatment on the liquid phase material flow, separating to obtain deasphalted asphalt and deasphalted oil, recycling the deasphalted oil to the fixed bed residual oil hydrogenation reaction zone in the step (1) for carrying out the hydrogenation reaction, and carrying out delayed coking treatment on the deasphalted asphalt to obtain low-sulfur petroleum coke; and introducing the gas-phase material flow into a hydrocracking reaction zone filled with a hydrocracking catalyst to carry out hydrocracking reaction, so as to obtain heavy naphtha.
The reaction conditions and product distribution and yields of the fixed bed residuum hydrogenation reaction zone, the hydrocracking reaction zone, the solvent deasphalting treatment, and the delayed coking treatment are shown in table 3.
Example 2
This example is similar to the method of operation of example 1, except that:
the residual oil raw material is residual oil B, and the consumption of the dispersion type catalyst is 0.3wt%;
the reaction conditions and product distribution and yields of the fixed bed residuum hydrogenation reaction zone, the hydrocracking reaction zone, the solvent deasphalting treatment, and the delayed coking treatment are shown in table 3.
Example 3
This example is similar to the method of operation of example 1, except that:
the residual oil raw material is residual oil B, and the consumption of the dispersion type catalyst is 0.8wt%;
the reaction conditions and product distribution and yields of the fixed bed residuum hydrogenation reaction zone, the hydrocracking reaction zone, the solvent deasphalting treatment, and the delayed coking treatment are shown in table 3.
Example 4
This example is similar to the method of operation of example 1, except that:
the dispersion type catalyst is a dispersion type catalyst FS-2;
the reaction conditions and product distribution and yields of the fixed bed residuum hydrogenation reaction zone, the hydrocracking reaction zone, the solvent deasphalting treatment, and the delayed coking treatment are shown in table 3.
Comparative example 1
This comparative example is similar to the procedure of example 1, except that:
the method adopts the residual oil hydrogenation method in the prior art, and specifically:
in the presence of hydrogen, introducing the residual oil B into a fixed bed residual oil hydrogenation reaction zone filled with a residual oil hydrogenation catalyst for hydrogenation reaction, and separating hydrogenated oil obtained after the hydrogenation reaction in a hot high-pressure separator to obtain atmospheric residual oil (> 350 ℃) which is used as a raw material of a catalytic cracking device to obtain catalytic cracking gasoline.
The reaction conditions and product distribution and yields of the fixed bed residuum hydrogenation reaction zone, the hydrocracking reaction zone, the solvent deasphalting treatment, and the delayed coking treatment are shown in table 3.
Comparative example 2
This comparative example is similar to the procedure of example 1, except that:
the amount of the dispersion catalyst is 3wt%;
the reaction conditions and product distribution and yields of the fixed bed residuum hydrogenation reaction zone, the hydrocracking reaction zone, the solvent deasphalting treatment, and the delayed coking treatment are shown in table 3.
Comparative example 3
This comparative example is similar to the procedure of example 1, except that:
the amount of the dispersion catalyst was 0.005wt%;
the reaction conditions and product distribution and yields of the fixed bed residuum hydrogenation reaction zone, the hydrocracking reaction zone, the solvent deasphalting treatment, and the delayed coking treatment are shown in table 3.
TABLE 3 Table 3
As is clear from table 3, when the amount of the dispersed catalyst added is too low, both the residuum conversion and the heavy naphtha yield are poor, and when the amount of the dispersed catalyst added is too large, the residuum conversion and the heavy naphtha yield are comparable, but on the one hand, the catalyst cost is greatly increased, and on the other hand, too much addition of the dispersed catalyst causes clogging of the fixed bed residuum hydrogenation apparatus, and the operation period is greatly shortened.
When the method is adopted for hydrogenating residual oil, the stability of the hydrogenated oil is ensured, the yield of heavy naphtha is higher, low-sulfur petroleum coke with the sulfur content lower than 3.0wt% can be produced, the conversion rate of the residual oil is greatly improved, and the transformation utilization of the existing fixed bed residual oil hydrogenation device can be realized under the condition that the operation period is not shortened.
The preferred embodiments of the present invention have been described in detail above, but the present invention is not limited thereto. Within the scope of the technical idea of the invention, a number of simple variants of the technical solution of the invention are possible, including combinations of the individual technical features in any other suitable way, which simple variants and combinations should likewise be regarded as being disclosed by the invention, all falling within the scope of protection of the invention.
Claims (26)
1. A process for hydrogenating residuum, the process comprising:
(1) Introducing a residual oil raw material, a dispersion type catalyst and deasphalted oil into a fixed bed residual oil hydrogenation reaction zone filled with a residual oil hydrotreating catalyst in the presence of hydrogen to carry out hydrogenation reaction to obtain hydrogenation generated oil, wherein the content of toluene insoluble matters in the hydrogenation generated oil is not more than 0.1wt%, and the use amount of the dispersion type catalyst is 0.02-0.8wt% based on the total weight of the residual oil raw material and the deasphalted oil;
(2) Introducing the hydrogenated oil into a hot high-pressure separator for separation to obtain a gas-phase material flow and a liquid-phase material flow containing hydrogenated residual oil;
(3) Subjecting the liquid phase stream to solvent deasphalting to obtain deasphalted asphalt and deasphalted oil recycled back to the fixed bed residuum hydrogenation reaction zone of step (1) for the hydrogenation reaction; and
introducing the gas-phase material flow into a hydrocracking reaction zone filled with a hydrocracking catalyst to carry out hydrocracking reaction to obtain heavy naphtha;
the dispersion type catalyst is a granular catalyst containing a metal element and a non-metal element, wherein the non-metal element is at least one of non-metal elements in IVA groups and VIA groups, and the metal element is at least one of metal elements in VB groups, VIB groups, IVA groups and VIII groups; the content of the metal element in terms of oxide is 5-20wt% based on the total weight of the dispersion catalyst, and the content of the nonmetallic element is 80-95wt%.
2. The method according to claim 1, wherein in step (1), the dispersed catalyst has an average particle diameter of 0.1 μm to 25 μm.
3. The method according to claim 1 or 2, wherein in the step (1), in the dispersed catalyst, the metal element is selected from at least one of Cr, V, mo, W, ni, fe, co and Sn, and the non-metal element is selected from at least one of C, si, S.
4. The process according to claim 1 or 2, wherein in step (1) the conditions of the fixed bed residuum hydrogenation reaction zone are at least: the hydrogen partial pressure is 1.0-22.0MPa, the reaction temperature is 330-470 ℃ and the volume space velocity is 0.1-3.0h -1 The volume ratio of hydrogen oil is 350-2000.
5. The process of claim 4 wherein the fixed bed residuum hydrogenation reaction zone conditions are at least: the hydrogen partial pressure is 8.0-21.0Mpa, the reaction temperature is 360-460 ℃, and the volume space velocity is 0.2-2.5h -1 The volume ratio of hydrogen to oil is 400-1500.
6. According to the weightsThe process of claim 1 or 2, wherein in step (1), the bulk density of the residuum hydrotreating catalyst is 300-900kg/m 3 The average pore diameter is 5-20nm, the pore volume is not less than 0.45ml/g, and the specific surface area is not less than 90m 2 /g。
7. The process according to claim 1 or 2, wherein in step (1), the residuum hydrotreating catalyst is selected from at least one of hydrodemetallization catalysts, hydro-guard catalysts, transition catalysts, hydrodesulphurisation denitrification catalysts.
8. The process according to claim 1 or 2, wherein in step (1), the residuum hydrotreating catalyst contains a support selected from at least one of alumina, silica, and titania, and an active metal element selected from group vib and/or group viii metal elements supported on the support.
9. The method of claim 8, wherein in the residuum hydroprocessing catalyst, the active metal element is selected from at least one of a nickel-tungsten combination, a nickel-tungsten-cobalt combination, a nickel-molybdenum combination, a cobalt-molybdenum combination.
10. The process of claim 8 wherein the active metal element is present in an amount of 0.05 to 25wt% on an oxide basis based on the total weight of the residuum hydroprocessing catalyst.
11. The process of claim 6 wherein the residuum hydrotreating catalyst further comprises at least one adjunct element selected from the group consisting of boron, germanium, zirconium, phosphorus, chlorine, and fluorine.
12. The process according to claim 11, wherein the total content of the auxiliary elements in elemental form in the resid hydrotreating catalyst is from 0.01 to 10wt%.
13. The process according to claim 1 or 2, wherein in step (1) the fixed bed residuum hydrogenation reaction zone contains at least 2 fixed bed reactors in series in sequence.
14. The process of claim 13 wherein the fixed bed residuum hydrogenation reaction zone contains from 2 to 6 fixed bed reactors in series in sequence.
15. The process according to claim 1 or 2, wherein in step (1) the residuum hydroprocessing catalyst has a bed void fraction e of greater than 0.40, the catalyst has a bed void fraction e= (bed volume-bed packing volume)/bed volume, and the bed volume and the bed packing volume are in the same units.
16. The process according to claim 1 or 2, wherein in step (1) the residuum feedstock is selected from at least one of atmospheric residuum, vacuum residuum, heavy oil.
17. The process of claim 1 or 2, wherein the residuum feedstock has a density at 20 ℃ of greater than 950kg/m 3 。
18. A method according to claim 1 or 2, wherein in step (2) the conditions of the hot high pressure separator at least satisfy: the temperature is 330-450 ℃, and the pressure is 5-22Mpa.
19. The method according to claim 1 or 2, wherein in step (3), the conditions of the solvent deasphalting treatment at least satisfy: the extraction temperature is 100-300 ℃, the pressure is 0.5-5MPa, and the volume ratio of the catalyst to the oil is (5-10): 1.
20. the process according to claim 1 or 2, wherein the solvent involved in the solvent deasphalting treatment is selected from C 5 -C 8 Alkane, C 5 -C 8 At least one of olefins, condensate and naphtha.
21. The process according to claim 1 or 2, wherein in step (3) the hydrocracking reaction zone conditions at least satisfy: the hydrogen partial pressure is 5.0-22.0MPa, the reaction temperature is 300-450 ℃, and the volume space velocity is 0.1-2.0h -1 The volume ratio of hydrogen oil is 350-2000.
22. The process according to claim 1 or 2, wherein the hydrocracking catalyst has a bulk density of 500-1200kg/m 3 The average pore diameter is 5-20nm, the pore volume is not less than 0.2ml/g, and the specific surface area is not less than 190m 2 /g。
23. The method according to claim 1 or 2, wherein the hydrocracking catalyst contains a carrier selected from at least one of alumina, silica and titania and an active metal element selected from at least one of nickel, cobalt, molybdenum and tungsten supported on the carrier.
24. The process according to claim 23, wherein in the hydrocracking catalyst the content of nickel and/or cobalt in terms of oxides is 0-30wt%, the content of molybdenum and/or tungsten in terms of oxides is 0-35wt%, and the sum of the contents of nickel, cobalt, molybdenum, tungsten in terms of oxides is greater than 0, based on the total weight of the hydrocracking catalyst.
25. The method of claim 1 or 2, further comprising subjecting the deoiled asphalt to a delayed coking process to obtain petroleum coke.
26. The method of claim 25, wherein the conditions of the delayed coking process at least satisfy: the outlet temperature of the heating furnace is 450-600 ℃, the pressure is 0.1-0.5MPa, and the circulation ratio is 0.1-1.
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| CN103102980A (en) * | 2011-11-10 | 2013-05-15 | 中国石油化工股份有限公司 | Combined process for in-depth conversion of residual oil |
| CN103789036A (en) * | 2012-10-26 | 2014-05-14 | 中国石油化工股份有限公司 | Combination processing method of inferior heavy oil |
| CN106544055A (en) * | 2015-09-16 | 2017-03-29 | 中国石油化工股份有限公司 | A kind of processing method of inferior heavy oil and/or poor residuum |
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| CN103102980A (en) * | 2011-11-10 | 2013-05-15 | 中国石油化工股份有限公司 | Combined process for in-depth conversion of residual oil |
| CN103789036A (en) * | 2012-10-26 | 2014-05-14 | 中国石油化工股份有限公司 | Combination processing method of inferior heavy oil |
| CN106544055A (en) * | 2015-09-16 | 2017-03-29 | 中国石油化工股份有限公司 | A kind of processing method of inferior heavy oil and/or poor residuum |
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