WO2024251722A1 - Procédé intégré pour la conversion complète d'une charge d'alimentation résiduelle - Google Patents

Procédé intégré pour la conversion complète d'une charge d'alimentation résiduelle Download PDF

Info

Publication number
WO2024251722A1
WO2024251722A1 PCT/EP2024/065304 EP2024065304W WO2024251722A1 WO 2024251722 A1 WO2024251722 A1 WO 2024251722A1 EP 2024065304 W EP2024065304 W EP 2024065304W WO 2024251722 A1 WO2024251722 A1 WO 2024251722A1
Authority
WO
WIPO (PCT)
Prior art keywords
stream
residue
stripper
hydrocracker
heated
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Ceased
Application number
PCT/EP2024/065304
Other languages
English (en)
Inventor
James J. Colyar
David DE GRUYL
Trushit Oza
Xavier Decoodt
Eric Peer
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Axens SA
Original Assignee
Axens SA
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Axens SA filed Critical Axens SA
Priority to CN202480038290.0A priority Critical patent/CN121358825A/zh
Publication of WO2024251722A1 publication Critical patent/WO2024251722A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

Links

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
    • C10G69/00—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process
    • C10G69/02—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only
    • C10G69/06—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only including at least one step of thermal cracking in the absence of hydrogen
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10B—DESTRUCTIVE DISTILLATION OF CARBONACEOUS MATERIALS FOR PRODUCTION OF GAS, COKE, TAR, OR SIMILAR MATERIALS
    • C10B55/00—Coking mineral oils, bitumen, tar, and the like or mixtures thereof with solid carbonaceous material
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10B—DESTRUCTIVE DISTILLATION OF CARBONACEOUS MATERIALS FOR PRODUCTION OF GAS, COKE, TAR, OR SIMILAR MATERIALS
    • C10B55/00—Coking mineral oils, bitumen, tar, and the like or mixtures thereof with solid carbonaceous material
    • C10B55/02—Coking mineral oils, bitumen, tar, and the like or mixtures thereof with solid carbonaceous material with solid materials
    • C10B55/04—Coking mineral oils, bitumen, tar, and the like or mixtures thereof with solid carbonaceous material with solid materials with moving solid materials
    • C10B55/08—Coking mineral oils, bitumen, tar, and the like or mixtures thereof with solid carbonaceous material with solid materials with moving solid materials in dispersed form
    • C10B55/10—Coking mineral oils, bitumen, tar, and the like or mixtures thereof with solid carbonaceous material with solid materials with moving solid materials in dispersed form according to the "fluidised bed" technique
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10B—DESTRUCTIVE DISTILLATION OF CARBONACEOUS MATERIALS FOR PRODUCTION OF GAS, COKE, TAR, OR SIMILAR MATERIALS
    • C10B57/00—Other carbonising or coking processes; Features of destructive distillation processes in general
    • C10B57/04—Other carbonising or coking processes; Features of destructive distillation processes in general using charges of special composition
    • C10B57/045—Other carbonising or coking processes; Features of destructive distillation processes in general using charges of special composition containing mineral oils, bitumen, tar or the like or mixtures thereof
    • 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
    • C10G9/00—Thermal non-catalytic cracking, in the absence of hydrogen, of hydrocarbon oils
    • C10G9/005—Coking (in order to produce liquid products mainly)
    • 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
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/107—Atmospheric residues having a boiling point of at least about 538 °C
    • 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
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1077—Vacuum residues
    • 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
    • C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
    • C10G2400/02—Gasoline
    • 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
    • C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
    • C10G2400/04—Diesel oil

Definitions

  • This invention relates to processes for hydrocracking heavy oils and oil residues such as vacuum gas oil, atmospheric residue and vacuum residue into substances having smaller molecules of greater utility.
  • crude oil is processed via distillation into various fractions such as naphtha, gas oil, and residuum.
  • fractions such as naphtha, gas oil, and residuum.
  • Each of these fractions has a number of potential uses, for example for the production of transportation fuels such as gasoline, diesel and kerosene, or as feed for some petrochemical and other process units.
  • Light crude oil fractions such as naphtha and some gas oils can also be used to produce light olefins and single ring aromatics via processes such as steam cracking, where the hydrocarbon feed stream is vaporized and diluted with steam and then exposed to very high temperature (800 °C to 860°C) furnace (reactor) tubes for short residence times ( ⁇ 1 second).
  • hydrocarbon molecules in the feed are converted into lighter molecules and molecules with a lower hydrogen to carbon ratio (e.g. olefins) when compared to the feed molecules.
  • the process also produces hydrogen as a useful byproduct and significant amounts of lower value by-products such as methane and C9+ aromatics and condensed aromatics (containing two or more aromatic rings in common).
  • heavier (or higher boiling) fractions such as atmospheric or vacuum residue are further processed in crude oil refineries to maximize the yield of lighter (distillable) products from the crude oil.
  • the treatment may be carried out by a process such as hydrocracking (whereby the hydrocracker feed is exposed to a suitable catalyst under conditions such that some portion of the feed molecules are broken down into lighter hydrocarbon molecules while being hydrogenated).
  • Hydroconversion processes disclosed herein may be used for reacting residuum hydrocarbon feedstocks at conditions of elevated temperatures and pressures in the presence of hydrogen and one or more hydroconversion catalyst to convert the feedstock to lower molecular weight products with reduced contaminant (such as sulfur and/or nitrogen) levels.
  • Hydroconversion processes may include, for example, hydrogenation, desulfurization, denitrogenation, cracking, conversion, demetallization, and removal of, Conradson Carbon Residue (CCR) or asphaltenes removal, etc.
  • CCR Conradson Carbon Residue
  • residuum hydrocarbon fractions are defined as a hydrocarbon fraction having boiling points or a boiling range above about 340° C. but could also include whole heavy crude processing.
  • Residuum hydrocarbon feedstocks that may be used with processes disclosed herein may include various refinery and other hydrocarbon streams such as petroleum atmospheric or vacuum residua, deasphalted oils, deasphalter pitch, hydrocracked atmospheric tower or vacuum tower bottoms, shale-derived oils, coal- derived oils, tar sands bitumen, tall oils, bio-derived crude oils, black oils, as well as other similar hydrocarbon streams such as heavy oil obtained from the pyrolysis of plastic or tire materials, or a combination of these, each of which may be straight run, process derived, hydrocracked, partially desulfurized, and/or partially demetallized streams.
  • residuum hydrocarbon fractions may include hydrocarbons having a normal boiling point of at least 480°C, at least 524°C, or at least 565° C.
  • the residue feedstock has a nickel plus vanadium content of between 1 and 1500 ppmw and more typically between 50-500 ppmw, a sulfur content of between 0.1 and 8.0 weight percent and more typically between 2.0 and 5.0 percent weight, CCR content of between 1 .0 and 50.0 percent weight and more typically between 10 and 25 percent weight, nitrogen content of between 500 and 8000 ppmw and more typically between 2000 and 5000 ppmw, and an asphaltene content of between 1 and 30 percent weight and more typically between 5 and 15 percent weight .
  • the residue feedstock may include at least one of petroleum atmospheric or vacuum residua, deasphalted oils, deasphalter pitch, hydrocracked atmospheric tower or vacuum tower bottom shale-derived oils, coal-derived oils, bioderived crude oils, tar sands bitumen, tall oils, black oils.
  • the residue feedstock may be derived from one or more of Arab Heavy, Arab Light, Arab Medium, Kuwait Export, Basrah Light, Rubble,oane, Oman, Upper Zakam, REBCO, Kumkol, Ural, Azeri Light, Siberian Light, Siberian Heavy, and Tengiz petroleum crude oils.
  • the shale-derived oils may be generated either in an in situ extraction process or an above ground oil shale retorting process.
  • the coal gasification byproduct oils may be derived from a fixed-bed gasifier or a fluid-bed gasifier or a moving-bed gasifier.
  • the coal-derived oils may be derived from a pyrolysis unit or a hydrothermal liquefaction unit or a catalytic hydroliquefaction unit.
  • Heavy refinery stream hydrocracking is typically carried out at high pressures and temperatures and therefore has high capital costs. Hydrocracking of residue is not a complete conversion process, there is an unconverted oil (UCO) by-product stream from the process. This yield of this stream can be from about 5 to 50% depending on the operating conditions of the hydrocracking unit and the reactivity of the hydrocracker feed.
  • the UCO is typically of poorer quality than the feed to the hydrocracker - higher in density and with more contaminants such as sulfur, CCR, nitrogen, asphaltene and metals.
  • This UCO stream can be blended with lighter streams like diesel in order to be used as a fuel oil, which downgrades the value of the diesel stream.
  • Coking is a thermal process that allows refineries to process heavier hydrocarbons present in oil, tar sands and other hydrocarbon sources.
  • coking thermal processes use complex thermal decomposition (or “cracking”) in the absence of catalyst or hydrogen to convert very heavy bottoms of crude oil to lower boiling, higher value hydrocarbon liquid products.
  • the feed for such coking processes usually consists of refinery streams that cannot be economically further distilled, catalytically cracked, or otherwise processed to create fuel mixture streams. Typically, these materials are not suitable for catalytic operations due to rapid poisoning of the catalyst with ash or metals.
  • Common coking feeds include bottoms from atmospheric distillation, bottoms from vacuum distillation, residual catalytic cracking oils, and residual oils from other processing plants such as hydrocrackers.
  • the yield of light hydrocarbon liquids from coking is generally lower than achievable by residue hydrocracking ( ⁇ about 70%).
  • residue hydrocracking ⁇ about 70%.
  • the heaviest components of the coker feed are converted to a solid product, petroleum coke. This material can be used as a fuel for power generation and the production of metals and brick.
  • Three types of coking processes used for crude oil at refineries to convert heavy hydrocarbon fractions into lighter hydrocarbons and petroleum coke include delayed coking, fluidized coking, and fluid coking combined with gasification.
  • petroleum coke is considered a by-product that is allowed in the interests of more complete conversion of refinery residues into lighter hydrocarbon compounds.
  • fluid coking combined with gasification the coke product is gasified to produce a syngas, leaving no solid by-product at the end.
  • the resulting liquid hydrocarbons and other products are transferred from the coking unit to a distillation column for separation.
  • Heavier liquid cracking products e.g., gas oil
  • FCCUs fluidized catalyst
  • the current state-of-the-art is to have completely separate residue hydrocracking and coking plants.
  • the residue hydrocracker products are first separated in an atmospheric fractionator and the atmospheric residue sent to a vacuum tower.
  • the bottoms from the vacuum tower are the feed to the coking unit, which also contains a fractionator tower to separate the liquids generated in the coking process.
  • the residue hydrocracker’s atmospheric and vacuum fractionation sections are costly in terms of capital and operating expenses, and depending on the feed processed and the operating conditions employed, can exhibit high levels of fouling that can lead to premature shutdown for tower cleaning (particularly the vacuum tower), incurring high maintenance costs.
  • An advantage of this invention is to remove the pieces of equipment likely to incur coking in the residue hydrocracking unit (where coking is not desirable) and have the coking occur in the coking unit.
  • the process further comprises: f) feeding said fractionator vapor stream, said stripper vapor stream from step b,) and said hydrocracker vapor stream from step a) to gas a recovery unit; and g) feeding said coker naphtha stream from step e), said stripper naphtha stream from step b), said light gas oil stream, and said heavy gas oil stream to downstream processing units for production of final petroleum products.
  • Applicant’s have disclosed a processing scheme for efficiently and effectively integrating hydrocracking and coking for the complete conversion of residue feedstock wherein optionally the steam stripper from step b) above creates a stripper naphtha stream, a stripper vapor stream containing nominally C4 and lighter hydrocarbon gases and sour gases, a stripper bottoms stream, said stripper bottoms stream comprising a heavy fraction and a light fraction, and a residue hydrocracker diesel stream having a typical nominal boiling range of between 180-350°C.
  • Figure 1 is a schematic showing Applicant’s process for integration of hydrocracking and coking for the complete conversion of residue feedstock.
  • Figure 2 is a schematic showing an optional configuration of Applicant’s process wherein a side draw is taken from the residue hydrocracker stripper column and this stream routed directly to downstream processing.
  • Figure 1 is a schematic showing Applicant’s process for efficiently and effectively integrating hydrocracking and coking for the complete conversion of residue feedstock.
  • a residue feedstock 10 is first processed along with hydrogen and catalyst (both not shown) in a residue hydrocracker unit 20 to partially convert the residue feedstock 10 and produce a hydrocracker gas stream 9 and a liquid conversion product stream 11 that comprises light hydrocarbon liquids from the cracking of the residue feedstock and unconverted residue.
  • the residue hydrocracker unit 20 operates at a reactor temperature of between 350-450°C, an inlet pressure of between 70-210 barg, and a space velocity of between 0.05 to 1 .5 hr 1 but preferably between 415-430°C, an inlet pressure of between 100-175 barg, and a space velocity of between 0.1 -0.3 hr 1 .
  • the residue hydrocracker unit 20 may consist of one or more ebullated-bed reactors, one or more slurry bed reactors, one or more fixed bed reactors or some combination of the above.
  • the residue hydrocracking reactor(s) may employ a catalyst or catalysts, especially a granular catalyst comprising, on an amorphous substrate, at least one metal or metal compound with a hydrogenating function.
  • This catalyst can be a catalyst comprising metals of group VIII, for example nickel and/or cobalt, most often in combination with at least one metal of group VIB, for example molybdenum and/or tungsten.
  • a catalyst comprising from 0.5 to 10% by weight of nickel and preferably from 1 to 5% by weight of nickel (expressed as nickel oxide NiO), and from 1 to 30% by weight of molybdenum and preferably from 5 to 20% by weight of molybdenum (expressed as molybdenum oxide MoOs) on an amorphous metal substrate
  • This substrate will be chosen from, for example, the group formed by alumina, silica, silica-aluminas, magnesia, clays and mixtures of at least two of these minerals.
  • This substrate can likewise contain other compounds, and, for example, oxides chosen from the group formed by boron oxide, zirconia, titanium oxide, and phosphoric anhydride.
  • the liquid conversion product stream 11 from the residue hydrocracker unit 20 is routed along with a separate steam stream 12 to a steam stripper 22.
  • the steam stripper 22 removes dissolved light gases (nominally C4 and lighter hydrocarbons and sour gases) 8 and also separates the liquid conversion product stream 11 into a residue hydrocracker naphtha stream 13 (for instance with a typical nominal boiling range of isopentane (82°C) to 180°C) and a stripper bottoms stream 14 (with a typical nominal boiling range of greater than 180°C).
  • the stripper bottoms stream 14 which serves as the feedstream for the coke drums in the coking unit, (24 and 24a), do not contain the lighter residue hydrocracker naphtha products 13, thus reducing the size of the coke drums required for processing the feed.
  • the removal of the residue hydrocracker naphtha stream 13 avoids co-mingling the coker naphtha stream 30 and residue hydrocracker naphtha 13. This is important since these streams require different downstream processing conditions and catalysts mainly due to the silicon compounds and diolefins found in a typical coker naphtha but not in a typical residue hydrocracker naphtha.
  • the stripper bottoms stream 14 contains all of the unconverted residue (also called in the present invention as “heavy boiling fraction” which has typically nominal 540°C+ boiling range) as well as conversion products from the residue hydrocracker (also called in the present invention as “light boiling fraction” having nominal 180-540°C boiling range) and, as mentioned above, comprises the feed to the coking unit.
  • the stripper bottoms stream 14 is first routed to a heater unit 23 for heating.
  • the heater may be a fuel gas-fired or oil- fired heater or an electric heater.
  • the stripper (heated) bottoms stream 14 which comprises a heavy boiling fraction (nominal 540°C+) and a light boiling fraction (nominal 180-540°C) is treated in a coking unit wherein said heated heavy boiling fraction from said heated stripper bottoms stream produces a solid coke product and a light converted residue product stream (via cracking).
  • the nature of the coking unit is such that the heated light boiling fraction of the heated bottoms stream passes through said coking unit substantially unconverted (less than 20% of this fraction converts).
  • the coking unit can be a delayed coking unit which is a batch process typically utilizing pairs of coke drums. As one is being filled with heated feed, the coke is being removed from the second via a hydraulic process using high-pressure water.
  • the coking unit can be a fluid coking unit, with or without gasification, which is a different process, more akin to fluid catalytic cracking. Fluid coking is a continuous process in which coke is continuously removed and at least partially used to provide heat for the process in place of the heater 23.
  • Fluid cokers operate at higher temperatures than delayed cokers (typically 510- 570°C).
  • the drawings are representative of a delayed coking unit. Two coke drums 24 and 24a are indicated in this drawing but it is possible to have configurations utilizing different numbers of coke drums.
  • the feed to the coke drums is heated to typically 450- 490°C and the drums typically operate at a pressure of 2.0-8.0 barg.
  • the final conversion of the residue feedstock 10 is completed with gas products and light liquid products produced and, depending on the coking technology selected, a solid coke product may also be produced.
  • the coke drums 24 and 24a produce a combined hydrocracked product stream 16 comprising a liquid product (of a typical nominal boiling range of isopentane (82°C) to 540°C) and a coker gas stream comprised of nominal C4 and lighter hydrocarbons and sour gases and a coke product 15.
  • the combined cracked product stream 16 is thereafter sent to a coker fractionator 26.
  • the coker fractionator 26 produces a gas stream comprised of nominal C4 and lighter hydrocarbons and sour gas 17, a liquid coker naphtha stream 30 (typically nominal isopentane (82°C) to 180°C), a combined coker and hydrocracker light gas oil stream 31 (typically nominal 180-350°C), and from the column bottom, a combined coker and hydrocracker heavy gas oil stream 32 (typically nominal 350-540°C).
  • These streams (30, 31 , and 32) are routed to downstream processing for production of final products (not shown).
  • the fractionator vapor 17 is combined with overhead vapor from the residue hydrocracker stripper 8 and from the residue hydrocracker 9 and sent to a gas recovery section.
  • the invention alleviates the need for and cost of atmospheric and vacuum fractionators specific to the residue hydrocracker and associated heat exchange equipment. As stated, this equipment is a major source of fouling for residue hydrocracking units and its elimination will result in a large increase in the plant on-stream time.
  • the stripper bottoms are sent directly to the coker heater.
  • the operation of the coker will be identical to the current state of the art with the exception that the feedstock will contain a higher content of vacuum gas oil necessitating larger coke drums due to higher vapor velocity in the drums.
  • the inclusion of residue hydrocracker light products in the common atmospheric fractionator will result in a larger tower than in a stand-alone arrangement.
  • An advantage of the current invention is that there is no unconverted residue (UCO) stream to dispose of. All of the feed residue is converted to gases, light liquids, and (depending on the coking technology employed), a solid coke product.
  • Figure 2 shows an optional configuration wherein an additional side draw 6 comprising diesel fraction with a typical nominal boiling range of 180-350°C is taken from the residue hydrocracker steam stripper column 22 and this stream routed directly to downstream processing.
  • the effect of adding the side draw 6 would increase the cost of the stripper tower, but reduce the cost of the coker heater, coke drums and coker fractionator.
  • the current invention results in a more economical and more reliable process for hydrocracking/coking of heavy residue.
  • the invention configuration will save an estimated 25-30% of the cost of separate ebullated- bed/delayed coking fractionation sections and for certain feedstocks will increase the onstream time by 5 - 10%.

Landscapes

  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Engineering & Computer Science (AREA)
  • Organic Chemistry (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Physics & Mathematics (AREA)
  • Thermal Sciences (AREA)
  • Materials Engineering (AREA)
  • Dispersion Chemistry (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

La présente invention a pour object d'intégrer économiquement deux technologies bien connues pour fournir une unité de traitement intégrée économique pour la conversion complète d'une charge d'alimentation résiduelle. Les technologies utilisées sont l'hydrocraquage d'huile lourde, qui peut se faire par l'intermédiaire d'un procédé à lit bouillonnant, à lit fixe ou à lit de suspension, et la cokéfaction, qui peut se faire par l'intermédiaire d'une cokéfaction retardée ou d'une cokéfaction fluide (avec ou sans gazéification intégrée). L'invention peut s'appliquer plus particulièrement à l'hydrocraquage de résidus de CCR élevée et de résidus atmosphériques et sous vide de métaux où la cokéfaction du résidu d'hydrocraqueur non converti est la méthode la plus pratique et économique d'élimination de résidus d'hydrocraquage.
PCT/EP2024/065304 2023-06-08 2024-06-04 Procédé intégré pour la conversion complète d'une charge d'alimentation résiduelle Ceased WO2024251722A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
CN202480038290.0A CN121358825A (zh) 2023-06-08 2024-06-04 渣油原料完全转化的一体化方法

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US18/207,178 2023-06-08
US18/207,178 US20240409830A1 (en) 2023-06-08 2023-06-08 Integrated Process for Complete Conversion of Residue Feedstock

Publications (1)

Publication Number Publication Date
WO2024251722A1 true WO2024251722A1 (fr) 2024-12-12

Family

ID=91465318

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/EP2024/065304 Ceased WO2024251722A1 (fr) 2023-06-08 2024-06-04 Procédé intégré pour la conversion complète d'une charge d'alimentation résiduelle

Country Status (3)

Country Link
US (1) US20240409830A1 (fr)
CN (1) CN121358825A (fr)
WO (1) WO2024251722A1 (fr)

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6096191A (en) * 1998-10-28 2000-08-01 Uop Llc Process for hydrocracking a hydrocarbonaceous feedstock
US9452955B2 (en) * 2013-03-14 2016-09-27 Lummus Technology Inc. Process for producing distillate fuels and anode grade coke from vacuum resid
US20190390124A1 (en) * 2017-02-02 2019-12-26 Sabic Global Technologies B.V. A process for the preparation of a feedstock for a hydroprocessing unit and an integrated hydrotreating and steam pyrolysis process for the direct processing of a crude oil to produce olefinic and aromatic petrochemicals
WO2021133657A1 (fr) * 2019-12-26 2021-07-01 Saudi Arabian Oil Company Procédé et système d'hydrocraquage comprenant l'élimination de composés aromatiques polynucléaires lourds à partir de fonds d'hydrocraqueur par cokéfaction

Family Cites Families (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
KR101956407B1 (ko) * 2011-07-29 2019-03-08 사우디 아라비안 오일 컴퍼니 인터스테이지 증기 스트리핑을 갖는 수소화분해 공정
US9644157B2 (en) * 2012-07-30 2017-05-09 Headwaters Heavy Oil, Llc Methods and systems for upgrading heavy oil using catalytic hydrocracking and thermal coking
US11384300B2 (en) * 2019-12-19 2022-07-12 Saudi Arabian Oil Company Integrated process and system to upgrade crude oil

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6096191A (en) * 1998-10-28 2000-08-01 Uop Llc Process for hydrocracking a hydrocarbonaceous feedstock
US9452955B2 (en) * 2013-03-14 2016-09-27 Lummus Technology Inc. Process for producing distillate fuels and anode grade coke from vacuum resid
US20190390124A1 (en) * 2017-02-02 2019-12-26 Sabic Global Technologies B.V. A process for the preparation of a feedstock for a hydroprocessing unit and an integrated hydrotreating and steam pyrolysis process for the direct processing of a crude oil to produce olefinic and aromatic petrochemicals
WO2021133657A1 (fr) * 2019-12-26 2021-07-01 Saudi Arabian Oil Company Procédé et système d'hydrocraquage comprenant l'élimination de composés aromatiques polynucléaires lourds à partir de fonds d'hydrocraqueur par cokéfaction

Also Published As

Publication number Publication date
CN121358825A (zh) 2026-01-16
US20240409830A1 (en) 2024-12-12

Similar Documents

Publication Publication Date Title
CN115232639B (zh) 用于原油转化的系统和方法
RU2707509C2 (ru) Усовершенствованный способ конверсии тяжелого углеводородного сырья
EP2970787B1 (fr) Procédé et appareil de production de carburants distillés et de coke de qualité anode à partir d'un résidu sous vide
US9879188B2 (en) Integrated ebullated-bed hydroprocessing, fixed bed hydroprocessing and coking process for whole crude oil conversion into hydrotreated distillates and petroleum green coke
US9868915B2 (en) Slurry hydroconversion and coking of heavy oils
MX2014011112A (es) Integracion de la desafaltizacion con disolvente con hidroprocesamiento de resina y con coquizacion retardada.
WO2014205171A1 (fr) Hydrotraitement étagé à l'aide de solvants et hydroconversion de résidus
JP7466066B2 (ja) 液化廃棄物ポリマーを処理するための方法
JP5460224B2 (ja) 高芳香族炭化水素油の製造方法
US20120067775A1 (en) Two-stage, close-coupled, dual-catalytic heavy oil hydroconversion process
US20190078029A1 (en) Reactor staging for slurry hydroconversion of polycyclic aromatic hydrocarbon feeds
US9039890B2 (en) Two-stage, close-coupled, dual-catalytic heavy oil hydroconversion process
US20240409830A1 (en) Integrated Process for Complete Conversion of Residue Feedstock
MXPA01002304A (es) Proceso y aparato para mejorar cargas de hidrocarburos que contienen azufre, metales y asfaltenos.
WO2013126364A2 (fr) Procédé d'hydroconversion de pétrole lourd à double catalyse, monobloc, à deux zones, utilisant un hydrotraitement amélioré
CN110776953B (zh) 包括固定床加氢处理、两次脱沥青操作和沥青的加氢裂化的用于处理重质烃原料的方法
WO2022020802A1 (fr) Intégration d'unités d'hydrocraquage et de cokéfaction à lit bouillonnant
EP4613830A1 (fr) Procédé de valorisation d'hydrocarbures résiduels craqués
US12116536B1 (en) Process and apparatus for converting crude oil to chemicals
WO2012170167A1 (fr) Procédé d'hydroconversion d'huile lourde à deux catalyseurs, à couplage étroit, à deux étages

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 24731853

Country of ref document: EP

Kind code of ref document: A1

WWE Wipo information: entry into national phase

Ref document number: 202647000986

Country of ref document: IN

NENP Non-entry into the national phase

Ref country code: DE

WWP Wipo information: published in national office

Ref document number: 202647000986

Country of ref document: IN