SA519401603B1 - Conversion process comprising fixed-bed hydrotreating, separation of a hydrotreated residue fraction, and a step of catalytic cracking for the production of marine fuels - Google Patents

Abstract

The invention relates to a process for the treatment of a hydrocarbon feedstock which makes it possible to obtain a heavy hydrocarbon fraction having a low sulfur content, said process comprising the following stages: a) an optional hydrodemetallization stage, b) a hydrotreating stage, c) a stage of separation of the effluent resulting from the hydrotreating stage b), d) a catalytic cracking stage on a portion of the hydrotreated effluent, e) a stage of separation of the effluent resulting from the catalytic cracking stage d), f) a mixing stage, so as to obtain a fuel oil which can be used as marine fuel. Figure 1 to be published.

Description

conversion process including fixed bed hydrotreatment; hydrotreated residual fraction separation; and a catalytic cracking step to produce marine fuel

CONVERSION PROCESS COMPRISING FIXED-BED HYDROTREATING,

SEPARATION OF A HYDROTREATED RESIDUE FRACTION, AND A STEP

OF CATALYTIC CRACKING FOR THE PRODUCTION OF MARINE FUELS

Full description Background of the invention Heavy hydrocarbon containing The present invention relates to the purification and conversion of hydrocarbon fractions

Sulfur including, among others, sulfur-based impurities More specifically related to a process for converting heavy petroleum feedstocks of an air-residue type and/or a vacuum-residue type to produce heavy fractions that can be used as fuel oil stocks; Specifically as stocks of 5 bunker oil; It has a low sediment content. kerosene naphtha kerosene The process according to the invention enables the production of atmospheric distillates (naphtha (C4 to C1) vacuum distillates and light gases o (diesel) and diesel among ore conversion processes Heavy petroleum feed of an atmospheric residue type and/or a basic type in modern refineries for the production of vacuum residue dle; now the catalytic cracking of residues 0 olefins 016005 and certain distillates. As a result of the impurity content of certain feedstocks of G 9 22 and 2 = 6 impurities from atmospheric residue and/or vacuum residue type » Hydrotreatment units are often installed for tailings to reduce the content of impurities, namely sulfur, metals and Conradson carbon 0. (CCR) as le The throughput from the hydrotreating stage is subjected to a stage separation which makes it possible to remove gases and atmospheric distillates.The atmospheric residue produced in the stage of separation is sent to catalytic cracking.

Catalytic cracking is also a process that makes it possible to process lighter feed ores; specifically vacuum distilled materials; which may also undergo intermediate hydrocracking or hydrotreatment prior to the catalytic cracking stage. Catalytic cracking is known as FCC (Fluid Catalytic Cracking) RFCC 4 (Cracking 5) Residue Fluid Catalytic Cracking RFCC 3 FCC are processes for converting vacuum distillates and/ or distillation residues that make it possible to obtain products in particular - acidic and dry gases (mainly: “(C2” C1 125 H2) _ liquefied petroleum gases containing molecules C3 -C4 ' 10 - gasolines containing at least 780 Compounds with boiling points between 30 and 220°C (das standard point); sometimes separate into light gasoline, known as LCN, and into heavy gasoline, known as HCN (heavy cracked naphtha); - A light distillate known as LCO (LCO) Light Cycle Oil containing at least 280 compounds having a boiling point between 5360 5 220 - A heavy distillate known as HCO ( Heavy Cycle Oil containing at least 0 compounds having a boiling point between 360°C and 440°C; - optionally a residue or slurry which is dale purified from the catalyst particles it contains in order to obtain refined oil (CO) clarified oil or (DO) decanted oil. 0 This residue contains at least 780 compounds with a boiling point greater than 440°C. may not be separated in the process; Then this mixture contains at least 780 compounds having a boiling point above 360"C. In continuation of the text; the term heavy cycle oil or

HCO to specify any lot resulting from the FCC or RFCC catalytic cracking stage containing at least 780 compounds having a boiling point higher than 360'. It is understood that such lot may be subject to the catalyst particle separation stage. Described Quality requirements for marine fuels in ISO 7 The specification related to sulfur is henceforth linked to SOX emissions (IMO MARPOL Annex VI).This is reflected in a recommendation for a sulfur content of less than or equal to 70.5 by weight outside of the Emissions Control Areas (ECAs) for 2020-25; and less than or equal to 70.1 by weight in 50/5. According to MARPOL Annex VI, a ship may therefore use sulfur-based fuel oil provided that it is The ship is equipped with a propellant gas treatment system which makes it possible to reduce lila

0 sulfur oxides. in dlls the absence of fuel gas treatment on the ship; It is necessary to use fuels that have a low sulfur content formed from “low sulfur stocks” that generally result at least in part from a process that carries out hydrodesulfurization.

8217 150 also describes other specifications that vary according to fuel class and type

5 fuel; The standard that distinguishes two families: marine distillates (less viscous) and marine leftover fuels.

Fuels used for marine transport may generally include atmospheric distillates; Material

vacuum distillation Air residues and vacuum residues resulting from direct distillation or resulting from a process

filtering namely the hydrotreating process and conversion process; These rations may be used alone or as a mixture in different proportions in order to comply with ISO 8217 1 standard.

for fuel of the retarded type; The characteristic that reflects combustion quality is measured by CCAl (Calculated Carbon Aromaticity Index). The correlation between the aromatic nature of the fuel and the ignition delay is known to one skilled in the art. A formula that makes it possible to calculate the aromaticity index is described; referred to in the description supplement as “CCA in the latest revision of ISO 8217. This particular format includes density

and fuel viscosity. For marine fuel grades RMG G (eg Grade 80 3 (RMG) 'ISO 8217 recommends a maximum CCAI of 870. In the context defined above, the applicant company has developed a new process that includes a treated residue stage Hydrogena is entirely vacuum-residue or atmospheric-residual in order to use them as cu(fuel) stocks; specifically the Sine-low sulfur (cu) stock of bunker fuel. surprisingly; It is shown that subjecting only a portion of the separated heavy fraction after hydrotreatment to the catalytic cracking stage (d) and sending the remainder to the mixing stage (f) makes it possible

0 1 Set the characteristics (cu) of the fuel produced; Specifically its sulfur content CCAl of A more specifically the invention shows that the control of tailings fractional flows of a vacuum hydrotreated tailing or atmospheric tailings that are not subject to catalytic cracking; And also the stage of mixing with a portion of the fractions resulting from catalytic cracking; makes it possible to improve the specification of the 'cu' of ship fuels, namely the sulfur content; viscosity; density wa .

There is an economic advantage in not looking for high quality for a particular grade of fuel bitumen.” In particular, marine fuel grades of the leftover type are lly less expensive than grades of the distillate type SUA. An approach as close as possible is necessary. Can be from the specified values of the specification provided that the production cost of the mixture is reduced by increasing the proportion of the lowest cost stocks to the maximum can specifically the leftover fractions of the airy leftover type or the vacuum leftover type but also the leftover stocks of

.RFCC or FCC resulting from HCO J LCO Type 0

In contrast to ell, there may be an advantage in optimizing the specification to obtain a product with

Superior or specific quality that can be upgraded more than a standard product. requires an excel 60/1 control; in oil

leftover fuel”; The aromatic fraction, Al, has poor combustion properties in a diesel engine

Compared to the shares richer in paraffins; such as atmospheric residues or vacuum residues; particulary

those that have been hydrotreated; Which has better combustion properties in a diesel engine. Controlling these proportions also has an impact on the flow rate and quality of feed materials for the catalytic cracking stage, and thus on the | For productivity and quality ¢ Specifically the sulfur content of the LCO and 00 fractions that may be incorporated into the fuel oil. The degree of hydrodesulfurization in the hydrotreatment stage is also a variable for potential tuning. Reducing the sulfur content of marine fuels (Taal) requires the construction of new facilities at new refineries or at existing refineries. The present invention may be a new unit but she shows the ability to (sale) use; at least two parts of the current units; In particular hydrotreating and/or catalytic cracking units. Subsequently; The current binding 0L can be reconfigured to the unit for tailings hydrotreating and to the unit for tailings catalytic cracking by modifying the throughput separation stage from the unit for tailings hydrotreating. In a similar way. A unit for tailings hydrotreatment followed by a separation unit may be installed prior to the existing catalytic cracking unit; In particular, the catalytic cracking unit is initially available for the treatment of vacuum distillates; This is done without reshaping or with (sale) minor shaping. 5 The earliest prior art cases related to the subject matter of the invention are the documents: 0) The international application No.: 083883/2013 dated 06/13/2013 AD. (b) The French application No.: 3000097 dated 06/27/2014 AD. Document (A) reveals (the application IIS 083883/2013) discloses a process for converting a heavy hydrocrion feedstock as specified, comprising steps for hydrometallurgy, hydrotreatment and separation equivalent to the claimed steps (a) through (c). Document (a) also discloses a catalytic cracking step (step (f) from document (a)) to cut through the segregation step.

Document 1 further discloses the step of separating the inflow from the catalytic cracking step and the step of mixing the atmospheric residue (and/or the vacuum distillate and/or the vacuum residue) with the LCO and/or HCO fraction produced from the catalytic cracking step to produce petroleum oil Has a viscosity of less than or 380 cst gold at 0°C; in relation to the recommendations for the conversion of MARPOL (sulfur content equivalent to or less than 70.5 by weight). atmosphere from the separation step (c).In fact, in Document ol) a catalytic cracking step of residue fraction and/or sale distilled under vacuum only is indicated (p. 20 lines 21-17 of Document ()). in addition to; Document A did not disclose that the cy of the resulting fuel had an aromatic index of 0 008/1 calculated Gay for standards 1508217 less than 870. The method under NC1 is therefore new in light of Document A. Document (b) (French Application No: 3000097) discloses a process for the conversion of hydrocrion ore (did) comprising hydrometallurgy and separation steps equivalent to steps (a) to (c) claimed. 5 Document (b) also discloses ) of a catalytic cracking step (step (e) of document (b)) oad of the throughput from the separation step. Document (b) further discloses the step of separating the throughput from the catalytic cracking step and a mixing step. An objective of the present invention is to provide a coupling conversion For the process and desulfurization of heavy petroleum feedstocks in order to produce fuel oils having an improved aromatic index of 00/8 and having a low sulfur content.Another objective of the present invention is to jointly produce, by the same process, atmospheric distillates (naphtha kerosene, diesel), distillates vacuum and/or light gases (Cl) to 04 (Ka) Upgrading the stocks of naphtha and diesel type in the refinery to produce fuel for the manufacture of high-performance vehicles

Engine and aircraft industry, for example, premium grade gasoline, jet engine fuel, and gas oil. GENERAL DESCRIPTION OF THE INVENTION The invention relates to a process for converting a heavy hydrocrion feedstock containing a fraction of at least hydrocriones having a sulfur content of at least 70.1 by weight; metal content of at least 10 ppm; an initial boiling point of at least 340°C and a final boiling point of at least 600°C; The process includes the following stages: (a) an optional hydrodemetallization stage in interchangeable reactors; Wherein the hydrocrion feedstock stage is in contact with hydrogen via a hydrogen demineralization catalyst 0; (b) a hydrotreating stage for a stable bottom of the throughput resulting from the hydrotreating stage (a) when the last stage or hydrocurion feedstock is performed in contact with the Hydrotreating Sling; 5 gas/liquid separation followed by atmospheric distillation that allows for at least one portion of a vacuum distillate type and one portion of a vacuum residue type; (3) a catalytic cracking stage of a portion of an atmospheric residue-type portion resulting from Stage (=) and/or a portion of a vacuum residue portion resulting from Stage (C); optionally as a mixture with at least a portion of a vacuum-distilled sala-type portion resulting from the phase separation (=) (e) the throughput phase separation from the catalytic cracking stage (d) that makes it possible to obtain at least one light gas oil das with a standard boiling range between 220

and 360"C; (LCO) and at least one heavy portion with a boiling point greater than 30 percent (HCO) from a portion of vacuum residue resulting from separation phase C with at least a portion of the portion of gasoil having Standard boiling range between 220 and 360"C; denoted by 0 and heavy ration having a boiling point greater than 360"C; denoted by the abbreviation HCO produced by separation phase (e); to obtain fuel oil that can be used as marine fuel with sulfur content Less than or equal to 5.70 by weight CCAI ¢ Calculated Lg of ISO 8217; Less than 870 Separation stage C may include vacuum distillation after atmospheric distillation with at least part of the residue sent Under one embodiment, the proportion of vacuum distillate obtained at the exit of the separation stage (=) is not entirely sent to the catalytic cracking stage (3) This process allows J to produce co For fuel oil and atmospheric distillates; vacuum distillates and light gases (C1) to 5 04) The dehydrogenation stage (a) is carried out at a temperature between 300 °C and 500 °C; Under absolute pressure between 5 MPa and 35 MPa” with a vacuum velocity of the hydrocrion feedstock HSV within the range of 0.1 hours*-1 to 5 hours”-1 and the amount of hydrogen mixed with the feedstock between 100 and 5000 standard cubic meters (5013) per cubic meter (M3) cubic meter 0 of liquid feedstock. The hydrotreating stage is carried out at a temperature between 300°C and 500°C; at absolute pressure between 5 MPa and 35 MPa” with a vacuum velocity of hydrocrion feedstock” commonly known as HSV; within a range of 1 hour-1 to 5 . “Aol

— 1 0 —

1 with an amount of hydrogen mixed with the feedstock between 100 and 50 005 standard cubic meters (SM3) per ia cubic meter (M3) of liquid feedstock.

The catalytic cracking stage has been carried out in at least one reactor operating as a catalytic cracking catalytic catalytic cracking » operating with a catalyst to feedstock ratio of between 4 and 15;

and with an outlet temperature of the reactor(s) between 450 and 600°C.

The fraction resulting from the separation stage (c) sent directly as a stock of fuel oil to the mixing stage (f) may consist only of atmospheric residue and represent between 740 and 795 by weight of the fuel oil obtained.

The fraction resulting from the separation stage (c) of the transmitter may be formed directly as a stock of fuel oil

0 to the mixing stage (F) only of the atmospheric residue representing between 740 and 790 by weight of fuel oil

which was obtained.

The fraction resulting from the separation stage (C) sent directly as a stock of fuel oil to the mixing stage (F) may consist of atmospheric residue and vacuum residue and represent between 740 and 795 by weight (cu) of the fuel obtained.

It is possible to add; in the mixing phase (and); At least one other fuel oil stock selected from dan crocin or cu share) gas from the separation stage (=) or process outflow stock selected from kerosene; direct distillation vacuum distillation gas oil or gas oil from the conversion process .

In this case; The flow stock fraction shall be less than 710 wt. of fuel oil produced; 0 Preferably less than 75 by weight of the resulting fuel oil. (Se) Selection of hydrocrion feedstock from atmospheric residues; direct vacuum distillation residues; crude oil; 6 crude oil harvested; stripping resins | ;

— 1 1 — bituminous sands or their derivatives, oil shale or its derivatives; Rocky origin or its derivatives taken alone or as a mixture; preferably The hydrocrion feedstock is selected from atmospheric residues, vacuum residues or mixtures of these residues. The hydrotreating stage (b) may include a first hydrodemetallization (HDM) stage (b1) conducted in one or more hydrodemetallization zones in dul-bottoms where the throughput phase is of the phase of or Feedstock and hydrogen in the absence of phase (a) in contact with a hydrometallurgical type catalyst” and a subsequent second hydrodesulfurization (HDS) step (b2) in one hydrodesulfurization zone or ST in dl lad where the phase The throughput is from the first hydrodesulfurization stage 0 (B1) in contact with the hydrodesulfurization catalyst. The hydrotreatment stage (b) may include a first hydrometallurgical (HDM) stage (b1) conducted in one or more hydrometallurgical zones in still beds; where the throughput stage is from stage (a); or feedstock hydrogen in the absence of phase A in contact with a hydrometallurgical type catalyst; A second subsequent transition stage (20) conducted in one transition zone 5 or more in still beds, wherein the first throughput hydrodesulfurization stage (b1) is in contact with les transition and a third hydrodesulfurization (HDS) stage suffix (b3) conducted in one or more hydrodesulfurization zones in dul Glad where the throughput stage of the second transition stage (20) is in contact with the hydrodesulfurization catalyst. The resulting fuel oil may exhibit a sulfur content less than or equal to 70.1 By weight. The resulting fuel oil can show a density at 15"C of less than 991 kg/m3 and a viscosity at 50"C of less than 380 cst. Brief Explanation of Drawings

— 2 1 — Figure 1: describes Figure 1; without limitation Scheme for carrying out the process according to the invention. Figure 1 describes a scheme for implementing the invention without limiting its scope. The hydrocarbon feedstock (1) and hydrogen (2) are in contact in the dehydrogenation stage (1) optionally in the Jabal ALE reactors, where the hydrogen stage (2) can be introduced at the entrance to the first catalytic bottom and between two bottoms. Stage A. The effluent (5) generated by the hydrometallurgy stage (A) in interchangeable reactors is sent to a fixed-bed hydrotreating stage (B), where an additional hydrogen stage (4) is introduced at the inlet of the catalytic bed the first and between two bottoms of stage B. In the absence of stage A, hydrogen feedstock (3) and hydrocarbon (4) are introduced directly into the hydrotreatment stage B. Optionally (Se) insert a known additional feedstock JAS feed joint cofeedstock (6) directly at the inlet of the hydrometallurgical stage (a) and/or the aye hydrotreatment inlet (b) via line (3). The effluent ( 7) resulting from a still bed hydrotreatment stage (b) 5 to a separation stage (c); comprising one or more separators (SEP) at different pressures and temperatures making it possible to obtain a liquid fraction (25) at least one gas fraction (23). Hydrogen-containing gas (23) can be fractured; Hydrogen sulfide ammonia and light hydrocarbons comprising 1 to 4 carbon atoms to recover a hydrogen-rich gas and thus 0 recycle it prior to the hydrometallurgy stage (a) and/or hydrotreatment stage (b). The liquid fraction (25) in this case is subjected to atmospheric distillation (ADU) to obtain at least atmospheric distillate materials of naphtha kerosene and type (cu) gas (24) and a portion of atmospheric residue type (9) das can be sent of type

— 3 1 — atmospheric residue (9) through line (26) of vacuum distillation (VDU) to obtain at least one cUt portion (8) of a vacuum distillate type and one cut portion (10) of Vacuum Residual Type Fraction (8) of the vacuum distilled material type is sent separately, or as a mixture with a section of cut Las (9) of an air residual type via line (11) or as a mixture with a section of das (10) of a vacuum residue type through line (13); to the catalytic cracking stage (d). Optionally additional feedstock (ad) can be sent as cofeedstock (15) to stage (d) . A portion of lot (9) of the atmospheric residual type through line (12) and/or a portion of lot (10) of the vacuum residual type through line (14) is not subjected to catalytic cracking stage (D) 0 and is directly dispatched to the mixing phase (f). The effluent (16) from the catalytic cracking stage (d) is sent to the separation stage (2) making it possible to obtain at least one light distillate LCO type (19) and at least one heavy distillate of type HCO (20). sale) The portion resulting from the separation stage (e) may preferably be recycled with a portion of the light distillate and/or the heavy distillate 5; At the inlet of the hydrotreatment stage (A) via line (18) and/or the inlet of the hydrotreatment stage (B) via line (17). At least a portion of the light distillate type LCO (19) and/or at least a portion of the heavy distillate type HCO (20) resulting from separation stage (e) is mixed; It will optionally be completed by one or more stream repositories outside the process (22); during mixture phase (F) 0 with a vacuum residue (14) and/or atmospheric residue (12) resulting from separation phase (C); for the purpose of obtaining one marine fuel (21) At least.Detailed description:

— 4 1 — Feeding raw materials usefully; The feedstock treated in the process according to Ble's invention shall be for a hydrocarbon feedstock exhibiting an initial lle point of at least 340"C and a final boiling point of at least 600"C. The hydrocrion feedstock according to the invention can be selected from atmospheric residues; direct distillation vacuum residue 6 crude zabut 6 crude zabut extracted ' stripping resins | for asphalt » asphalt or tar de-asphalt »; residues from conversion processes » aromatic extracts from lines for the production of lubricant stocks; tar sand or glide, shale oil or its derivatives; Oils of rock origin or gli. Taken alone or as a mixture. In the present invention; Preferably, the treated feedstock should be made from atmospheric residues, vacuum residues, or mixtures of these residues. The hydrocarbon feedstock processed in the process may contain, among other things; On sulfur-based impurities 0 the sulfur content may be at least 70.1 wt » preferably at least 70.5 wt » preferably at least 71 wt and most preferably at least 72 wt. The hydrocarbon feedstock processed in the process may contain; among others; on metal inclusions; at contents greater than 10 ppm; Specifically, nickel and vanadium. The sum of the contents of Jul) and vadium is generally in the order of 10 ey ppm over J to less ¢ preferably at least 0 ppm. It is preferable to use raw materials as is. in an alternative way Feedstocks can be diluted with additional feedstock known as a common feedstock. This combined feedstock may be a hydrocrion fraction or a mixture of 0 hydrocarbon fractions; (Ally can be preferably selected from products resulting from FCC or FCC process) light cycle (LCO) or cycle oil (Cid fraction ALE HCO) or cu) heavy cycle) 'cu) decanter' (FCC alana fraction 'cu) gas' specifically a fraction produced by atmospheric or vacuum distillation; For example; vacuum gas oil or that could come from

- 15 -

another refining process; such as coking or viscosity reduction. Bad can be de-asphalt oil

deasphalted oil (DAO) for one or more lots usefully. Common feed stocks can also be the result of a coal or biomass liquefaction process; aromatic extracts; or any stakes

other hydrocarbon; Or feedstock other than Jie cal diy pyrolysis oil.

If one or more additional feeding materials are introduced; They are referred to as common feedstocks; in operation; At any point in the process anyway; The heavy hydrocarbon feedstock according to the invention nonetheless constitutes the majority of the feedstock involved in the process according to the invention; 750 preferred over JI Very preferred 770 More preferred at least 780 Still

0 preferably at least 790% more by weight than the total hydrocrion feedstock treated by the process according to the invention.

in some cases; The common feed can be entered after the first low or subsequent lows; For example; at the inlet of the fixed bottom hydrometallurgical strip; or also at the entrance to the fixed-bed hydrotreating section; Or also at the entrance to the catalytic cracking sector.

The process according to the invention makes it possible to obtain conversion products, namely distillates formed during the hydrotreatment stage (b) and/or the catalytic cracking stage (d); which, after separation, may be sent to another refining process or combined into gasoline pools. The process allows for an air-residue type quota and/or a vacuum-residue quota resulting from the separation stage (=) ¢ that can be used as low sulfur-content fuel oil stock(s) during the mixing stage (f).

0 Optional Stage (A) Metal Hydrogen Type in Interchangeable Protection Reactors

During the dehydrogenation stage (of) the feedstock and hydrogen are contacted through a catalyst

Demineralization with charged hydrogen to at least two interchangeable reactors” under demineralization conditions

hydrogen. This optional Stage A procedure is preferred when the feedstock contains more than 50

ppm even more than 100 parts per million; of minerals and/or when it includes a feedstock

contain impurities that can cause a very rapid clogging of the Jie lead layer, calcium or iron derivatives; For example. The aim is to reduce the impurity content; and therefore to protect; from disruption and blockage» next hydrotreating stage; Hence the idea of protective reactors. Shielded hydrometallurgical reactors are used as switchable reactors (PRS) for the technique; A Permutable Reactor System as described in French Patent 2681871. These replaceable reactors are fixed bottom (Loses) placed prior to the fixed bed hydrotreating section and are equipped with lines and valves so that they can be interchanged Lad between this means That; for a system with two interchangeable reactors “Ra and 5”; Ra can be in front of Rb and vice versa. 0 can be placed each reactor Ra and 45 independently so as to change the catalyst without shutting down the remaining gall of the unit. This catalyst change (rinse; vacuum; sale; charge; vulcanize then [sale] run) is generally made possible by the conditioning section (a set of implement elements outside the main high-pressure loop). Switching to change the catalyst occurs when the catalyst is not Sufficiently active (metal poisoning, coke) and/or when the blockage leads to an excessively high pressure drop. According to any figure there may be more than two swappable reactors in the sector for dehydrogenation in the swappable reactors. During the swappable reactors Hydrodehydrogenation (oT) reactions occur in hydrogen demineralization (commonly known as HDM) but hydrodesulfurization reactions (commonly known as HDS) and hydrogen denitrification reactions (commonly known as HDN) also occur 0 associated with hydrogenation reactions; deoxyhydrogenation » dehydrogenation of the aromatic form; hydrogen isomerization hydro alkylation; Hydrocracking or hydrodesalphalation by means of Conradson's Creon reduction. Stage A is referred to as the hydrodemineralization stage due to the fact that it removes the majority of the minerals from the feedstock.

The dehydrogenation stage (a) may usefully be carried out in switchable reactors according to the invention at a temperature between 300 °C and 50009 °C; preferably between 513500 and 4309°C; and under absolute pressure between 5 MPa and 35 MPa; preferably between 11 MPa and 26 MPa; Specifically, between 14 MPa and 20 MPa. The temperature is usually set according to the desired level of hydrometallurgy and the target treatment time. In most cases, the vacuum velocity of the hydrocrion feedstock can be; Known as HOV which is defined as the flow rate by feedstock volume divided by the total catalyst volume; Within the range of 0.1 hours *-1 to 5 hours “1M Preferably 0.15 hours”-1 to 3 hours 1-8

Preferably over 0.2 hours 1-4 to 2 hours 1-4. The amount of hydrogen mixed with the feedstock can range from 100 to 5000 standard cubic meters per cubic meter of liquid feedstock; Preferably between 200 jie m³/m³ and 2000 jie m³/m³ and more preferable 300 m³ [gle m³ and 1000 m³/m³. The dehydrogenation phase (1) can be performed in industrially interchangeable reactors at

5 At least two fixed bottom reactors preferably with a liquid stream after. Preferably, the hydrogen demineralization catalysts used are known catalysts. Granular catalysts can include; on a support A metal compound or at least one metal that has a dehydrogenation function. Such catalysts can usefully be catalysts comprising at least one group VII metal (generally chosen from group 0 consisting of nickel and alkylates; and/or at least one group VIB metal preferably molybdenum and/ It is possible, for example, to use a catalyst consisting of 70.5 to 710 wt nickel preferably 71 to 75 wt nickel (expressed as nickel oxide (NIO) and 1 to 730 wt molybdenum preferably To be from 73 to 720 by weight of molybdenum (expressing die molybdenum oxide 1/003) on an inorganic support This support may be selected eg 5 from the group consisting of silica aluminates Silicates/aluminates Magnesia

Clay ores and mixtures of at least two of these minerals. Helpfully this support may include other demolition compounds; specifically selected oxides from the group consisting of boron oxide; phosphoric anhydride; and a mixture of these oxides. The use is often made of an alumina backing and optionally also of an alumina backing doped with phosphorous and optionally boron. When phosphoric anhydride (P205) is present, its concentration is less than 710 wt. Lexie, boron trioxide 8203 is present, its concentration is less than 710 wt. The alumina used can be lie for 7 (gamma) or 1 (eta) alumina This catalyst is often in the form of extrusions Maa) The content of group VIB and A/A metal oxides can be from 75 to 740 by weight; preferably from 75 to 730 wt.; percentage by weight; expressed as 0 metallic oxide; From the metal (or metals) of group VID to the metal (or metals) of group VIII generally between 20 and 1 and often between 10 and 2. The catalysts that can be used in phase A of the hydrodeamination process in ALE switch reactors are on Sebel (JU) described in EP 0113297 0113284 » US 6 5827421 7119045 5622616 5 50894635 Fixed bed hydrotreating stage (B ) Optionally introduce the throughput from the optional hydrometallurgical stage (a) with hydrogen into the fixed bottom hydrotreating stage (b) for AST contact from at least one hydrotreating catalyst. In the absence of the optional stage ( ) of the process Hydrogenation 0 in swappable shield reactors Feedstock and hydrogen are introduced directly into the fixed bed hydrotreating stage (B) for contact of at least one hydrotreating catalyst The hydrotreating catalyst(s) is used in one fixed bed reactor At least and preferably with a subsequent liquid stream.

hydrotreatment; Commonly known as HDT means catalytic treatments with the addition of hydrogen lly make it possible” i.e. to substantially reduce the content of metals; sulfur and other impurities; refining of the hydrocarbon feedstock; while improving the hydrogen-to-carbon ratio of the feedstock and while the feedstock is converted Partition into lighter rations in greater or lesser range Hydrotreatment specifically includes hydrogen denitrification reactions (commonly known as “HDS”), hydrodenitrification reactions (commonly known as (101!)); Hydrogenation (commonly known as HDM) is accomplished by hydrogenation reactions; hydrodeoxygenation »hydrogen hall deformation; hydrogen isomerization »hydrogen dealkylation; hydrocracking or hydrodesalkylation (Ges) via Conradson 0 carbon reduction.

according to a preferred alternative form; The hydrotreatment stage (b) comprises a first stage (b1) hydrodesulfurization (HDM) conducted in one or more cil-bed hydrodehydration zones and a second stage (b2) subsequent hydrodesulfurization (HDS) conducted in One or more hydrodesulphurization zones with fixed bottoms. During the first (B1) 5 dehydrogenation mentioned above; The resulting throughput is connected to phase (A); or feedstock and hydrogen in the absence of phase A; with a hydrometallurgical catalyst”; Under conditions of hydrometallurgy known to a person skilled in the art; precisely as described in stage (a); thereafter during said second stage (b2) for hydrodesulfurization; The throughput from the first stage (b1) for hydrometallurgy is connected to a hydrodesulfurization catalyst; under the conditions of hydrodesulfurization. This 0 describes the process; Known as (HYVAHL-FTM) for example in US Patent No.:

66.. A person skilled in the art easily recognizes that he is in the dehydrogenation stage (B1); La hydrogen demineralization reactions take place; but at the same time; Sa is also carried out by other hydrotreating reactions; Especially the reactions of hydrodesulfurization and hydrocracking. 5 likewise; in the hydrogen desulfurization stage (B2); Hydrogen desulfurization reactions are carried out »

but at the same time; Part of the other hydrotreating reactions are also performed; Especially the reactions of dehydrogenation and hydrocracking reactions. A person skilled in the art sometimes identifies a transition zone in which all types of hydrotreating reaction occur. According to another alternative form; Hydrotreatment stage (b) includes the first stage (b1) of the hydrodemetallurgy (HDM) process carried out in one or more hydrometallurgical zones in the dnl bottoms a subsequent second transition stage (2) carried out in the one or more transitional phases in still beds and a subsequent third stage of hydrodesulfurization (b3) carried out in one or more of the hydrodesulfurization zones in still beds. produced from stage (a); after that; During the aforementioned second transitional phase (B2); The throughput from the first dehydrogenation stage (B1) is connected to the catalyst (JE) under transition conditions” thereafter; during the aforementioned third stage of hydrodesulfurization (B3); The throughput from the second transition stage (20) contacts the hydrodesulfurization catalyst” under the conditions for hydrodesulfurization 5. The hydrodesulfurization stage (b1) according to the above alternative forms is particularly necessary in the absence of a hydrodesulfurization stage (a) In exchangeable protection reactors for the treatment of impurities and for protection of subsequent catalysts, the need for demetallurgical phase B1 according to the above alternative forms is also justified, in addition to demetallization phase A0 in exchangeable protector reactors when practical. The hydrometallurgy attempted during stage (a) is insufficient to protect the catalysts of stage (b), namely hydrodesulfurization catalysts.The hydrotreatment stage (a) according to the invention is carried out under hydrotreating conditions.It may be conducted characteristically at a temperature in the range between 300 500°C to 500°C; preferably in Range 5 between 350°C and 430°C; and under absolute pressure in the range 5 to 35 MPa

megapascal; Preferably in the range between 11 MPa and 26 MPa; Preferably in the range of 14 MPa and 20 MPa. The temperature is usually set by a person skilled in the art according to the desired level of hydrotreatment, the target nature (hydroderalization; hydrodesulfurization, etc.) and during the treatment. usually; The vacuum velocity of the hydrocrion feedstock can be “sale” known as the hourly space velocity (HSV) which is defined as the volumetric flow rate of the feedstock divided by the total catalyst volume in a range of 0.1 hours 1-2 1 to 5 hours 1-7 preferably 0.1 hours *-1 to 2 hours A 1 preferably more than 0.1 hours “*-1 to 1 dele *-1. The hydrogen content mixed with the feedstock can be in the range from 100 to 5000 M3 per cubic meter of feedstock (0 ill) preferably in the range from 200 M3/m3 to 2000 M3/m3; Thanks to more in the range from 300 scm/m3 to 0 scm/m3. Stage B hydrotreating can be performed on a scale

industrial in one or more reactors having a liquid after-stream. Preferably, the hydrotreating catalysts used are known catalysts. 5 can be granular catalysts including; on a support A metal compound or at least one metal that has a dehydrogenation function. Characteristically, these catalysts can be catalysts comprising at least one metal of group VIHT, generally chosen from the group consisting of nickel and quails; and/or at least one group VIB metal preferably molybdenum and/or tungsten. Probably; For example; use a catalyst consisting of 70.5 to 710 wt. of nickel; (expressed as molybdenum oxide (MOO3)) on an inorganic support. This support can be selected, for example, from the group consisting of aluminates, silicates/aluminates, magnesia, clay ores and mixtures.

of at least two of these minerals.

Distinctively, this support may include other demolition compounds; Specifically, selected oxides from the group consisting of boron oxide, zirconia, cyrea, titanium oxide, phosphoric anhydride, and a mixture of these oxides. The use is often made of an alumina backing and optionally also of an alumina backing doped with phosphorus and optionally boron. When phosphoric anhydride 0205 is present, its concentration is less than 710 by weight. When boron trioxide 8203 is present its concentration is less than 0 by weight. The alumina used can be 7 (We) or 17 (Eta) alumina. This catalyst is often in the form of extrusive materials. The total content of group VII VIB metal oxides may be from 73 to 740 by weight; usually from 75 to 730 wt.; percentage by weight; expressed as metallic oxide; From the metal (or metals) of group VID to the metal (or metals) of group

VIE 0 is generally between 20 and 1 and often between 10 and 2. In the case of the hydrotreating stage it includes a hydrodemineralization (HDM) stage (b1) followed by a hydrodesulfurization (HDS) stage (b2); It is preferable to use special catalysts and suitable hydrotreating operating conditions for each stage. The catalysts that can be used in the hydrometallurgical stage are (B1); For example described in the European patent documents 5 0113297 0113284 5 US 5221656 5827421 7119045 5622616 and 5089463. The catalysts that can be used in the hydrodesulfurization stage are (B2); For example described in Gilly EP 0113297 0113284 658908 4818743 or 6332976. Lad may use a mixed catalyst known as a transition catalyst; which is active in the hydrodesulfurization process and in the hydrodesulfurization process; Both for hydrodesulfurization section (B1) and for hydrodesulfurization section (20) as described in daly French Patent No.:

3. In dls the hydrotreating stage includes the hydrodemineralization (HDM) stage (B1); then the transition stage (b2) and then the hydrodesulfurization (HDS) stage (b3); 5 It is preferable to use special catalysts suitable for each stage and/or hydrotreating operating conditions suitable for each

phase. The catalysts that can be used in the hydrometallurgical stage are (B1); For example described in the European patent documents 0113297 7119045 5622616 and 5089463 US 5221656 5827427 The catalysts that can be used in the transition (B2); which are active in the hydrodesulfurization process and in the hydrodesulfurization process” for example (JB) shown in the French patent document No. 3. The catalysts that can be used in the hydrodesulfurization stage (B3); EP 0113297 0113284; US 658908 (4818743 or 6332976. Lad can use a JE catalyst as described in FP 0113297 0113284 for sectors (B1); (B2) and (B3). c) Separation of the hydrotreated infusion The process according to the invention comprises a separation stage (c) which makes it possible to obtain at least one Sle fraction, at least one fraction of the residue type con and optionally Lind at least one lot of the distillate type vacuum and at least one portion of a vacuum residue type The residue obtained at the completion of hydrotreatment stage (b) 5 comprises a liquid fraction of hydrocarbons and a gas fraction This fraction is usefully separated in at least one settling tank into one gas fraction at least and at least one heavy liquid fraction.This fraction may be separated by the use of separators well known to the person skilled in the art; namely, by using one or more sedimentation tanks that can operate at different pressures and temperatures; Optionally in combination with a steam or hydrogen removal device and with one or more distillation columns. 0 oda separators can be for example high— (HPHT) pressure high-temperature separators and/or high- (HPLT) separators. pressure low-temperature gas fraction contains gases; Specifically, NH3 (H2S (H2) and hydrocrions having 1-4 kreon atoms. C1-C4 hydrocarbons after cooling (lid) it is preferable to treat this gas fraction by means of

hydrogen purification»; This is to recover the hydrogen that is not consumed during the hydrotreatment and hydrocracking reactions. Hydrogen purification media can be amine washing; membrane A PSA system or several such devices arranged in series. The purified hydrogen can then be usefully recycled in the process according to the invention; after sale] Optional compression. The hydrogen may be introduced at the inlet of the hydrometallurgical stage ( ) and/or at various locations during the hydrotreatment stage (b). Jats Separation stage (c) also includes atmospheric distillation; optionally followed by vacuum distillation. In a first embodiment, the separation stage includes (c) In addition to simple gas/liquid separation, on at least one atmospheric distillate, wherein the liquid hydrocarbon fraction(s) obtained after separation by atmospheric distillation are fractionated to give at least one atmospheric distillate fraction and one residue fraction on The atmospheric distillate fraction(s) may contain fuel stocks (naphthalate kerosene and/or diesel) that can be commercially refined eg in a refinery to produce motor vehicle and aircraft fuel Fractions of the kerosene and/or diesel type may also be used as stocks in a marine distillate-type pool or as effluents in a residual Type 5 fuel oil or bunker bunker pool (according to 8217 150); for example, during the mixing stage (f). ) according to the invention “Load on at least one vacuum distillation whereby the liquid hydrocrion fraction(s) obtained after separation and/or the atmospheric residue fraction obtained after atmospheric distillation” Ua or LIS are fractionated by 0 vacuum distillation to give at least one vacuum distilled material fraction and at least one vacuum residual fraction. It is very desirable that the separation stage (c) Yl comprises atmospheric distillation; where the liquid hydrocarbon fraction(s) obtained after separation by atmospheric distillation are fractionated to give at least one atmospheric distillate fraction and at least one atmospheric residue fraction; Thereafter vacuum distillation

where and or each fraction of the atmospheric residue fraction obtained after atmospheric distillation by vacuum distillation is fractionated to give at least one vacuum distillate fraction and at least one vacuum residue fraction. The vacuum distillate fraction typically contains fractions of the vacuum gas oil type. The fractionation of the vacuum distillate can be partially improved as marine fuel of a distillate type (according to ISO 8217 (5) having a very low sulfur content) or also incorporated into a pool of bunker oil of a leftover type (according to ISO 8217) for example During the mixing phase (f), the distillate fraction is sent

emptyness Partially and wholly is preferred to the catalytic cracking stage (d). A portion of the heavy fraction formed from the atmospheric fraction and/or from the vacuum residue fraction is sent to the catalytic cracking stage (D). At least a section of broken air retarder can be used

0 and/or fractionation of the vacuum tail as fuel scum or as uy fuel stock; Optionally as stocks of bunker oil having a low sulfur content; during the mixing phase (f).

In a very preferred form the separation stage (c) is carried out with specific conditions that make it possible to improve the CCA by directing the atmospheric residue and/or vacuum residue fractions to the catalytic cracking stage (d) and/or mixing stage (f).

Subsequently; in the absence of vacuum distillation; This Directive shall make it possible for the hydrotreated atmospheric residue fraction emerging from the atmospheric distillation and released directly to the mixing stage (f) to be between 740 and 7955 by weight; preferably between 745 and 790 by weight; of fuel oil formed in the mixing stage (f). The remaining unreleased atmospheric residue is sent to the mixing stage (f) to the pit crushing stage (3).

similarly; in a scheme involving vacuum distillation and where there is no routing of the hydrotreated atmospheric residue fraction to the mixing stage (F) at the outlet of the atmospheric distillation; This directive should make it possible for the fraction of the vacuum hydrotreated residue released directly to the mixing stage (f) to be between 740 and 790; preferably between 750 and 785 by weight; of the cu of the fuel formed in the mixing stage (f). The remaining unreleased atmospheric residue is sent to the mixing stage (and) to the stage

— 6 2 — Catalytic cracking (D) as a mixture with at least a portion and preferably all of the vacuum distillate from the vacuum distillation. the fraction of the vacuum residual to the mixing phase (f); The dia must be the sum of the fractions of the atmospheric residue and the vacuum residue between 795 and 740 preferably between 85 745 oJ by weight; of cu) the fuel formed in the mixing stage (f). catalytic cracking stage (d) according to the invention; 1 At completion of the separation stage (=) a portion of a portion of the residue type Soll and/or a portion of the vacuum residue portion ¢ is sent as a mixture with at least a portion of das of 0 type of vacuum distillate optionally obtained in stage C to stage D of the catalytic cracking in at least one reactor operating as a catalytic cracking catalytic catalytic cracking catalyst “operating with a catalyst to feedstock ratio of between 4 and 15; preferably between 6 and 12; and with The outlet temperature of the reactor(s) is between 450 and 600"C; preferably between 480 and 580"C. Optionally, a co-feed is injected upstream of the catalytic cracking section (D). In the catalytic cracking unit; thermal equilibrium is provided by combustion of coke deposited on the catalyst during the reaction stage This combustion takes place in the regeneration zone by injecting air via a compressor known as the main air blower (MAB) typically; the catalyst enters the sale zone) the generation with coke content (defined as the weight of aad coke to catalyst weight) is between 70.5 and 71 and comes out of the aforementioned area with and coke content less than 70.01. 0 during this phase; The combustion gases are generated and exited from the regeneration area at temperatures between 640°C and 800°C. These combustion gases will undergo suffixes depending on the unit configurations; for a certain number of post-processing. The sale area) generation can be produced in two different generators; As in the RZIRTM process, which is marketed by Axens

— 7 2 — The Conradson carbon content of the feedstock (abbreviated by COR and defined as “eg” by ASTM D 482 standard) provides an assessment of the production of and coke during catalytic cracking. Depending on the conradson carbon content of the feedstock; and coke yields require specific unit dimensions in order to meet thermal equilibrium.

Subsequently; When the feedstock COR producing die shows a content and coke greater than the content needed to provide thermal equilibrium, the excess heat must be discharged. daa can be done for example and non-exhaustively; By installing a pickup cooler well known to someone skilled in the art; which constitutes an external cooling of the catalytic section of the generator by exchanging water; Thus aie produces steam production Sle pressure.

The catalyst from a catalytic cracking reactor typically consists of particles of medium diameter, generally between 40 and 140 µm and often between 50 and 120 µm. The gall cracking catalyst contains at least one matching matrix; as alumina silica or silica/alumina ¢ with or without the presence of Y-type Cul ga dispersed in this matrix. The catalyst may additionally comprise at least one zeolite that exhibits shape selectivity from one of the following structural species: MEL (le ex. 11-/251); MFI (eg ZSM- CHA (FER (EUO (NES)) 5 (eg MFS ((SAPO-34) or -MWW) may also include one of the following zepolites : IM= 5 NU-88 (NU-86 (NU-85 5), which also exhibit shape selectivity. The advantage of these zopolits that exhibit shape selectivity is that a better selectivity is obtained 0 for propylene/isobutene, i.e. a higher proportion of propylene/ Isobutene in fracturing ingots. The percentage of zeolites that show shape selectivity can vary in relation to the total amount of zeolites, as a function of the feed materials used and the construction of foamed products. In HES, 70.1 to 260 is used, preferably 70.1 to 740, specifically 70.1. to 730″ sll of zepolite which shows shape selectivity.

— 8 2 — Zeolites or zeolites may be dispersed in a silica-based matrix on alumina or on a silica/alumina ratio of zeolites (all combined zeolites); In terms of catalyst weight, it is usually between 70.7 by weight and 780 by weight; Preferably between 71wt and 750wt and more preferable between 75wt and 740wt. if sae is used zepolitat; They can be combined into a single matrix or into multiple different matrices. The content of zeolites that show shape selectivity in the total stock is less than 730 wt. The catalyst used in a catalytic cracking reactor may consist of an ultrastable type 1 zeolite dispersed in an alumina-silica or a silica/alumina matrix; to which ale is added an additive based on zeolite 251/5; And the quantity of 251/5 crystals in total stock is less than 730 wt. Said catalytic cracking stage can be carried out with a reactor functioning as an ela reactor as in units using a reactor functioning as a descending reactor. The catalytic cracking process enables the conversion of heavy hydrocarbon feedstocks into lighter hydrocrion fractions ranging from dry gases to a conversion residue. From (Gaal) Saal between the valleys; The following ratios are conventionally specified as a function of their composition or boiling point (standard ratio points given as 5 by sign): Dry and acidic gases (basically: 'C1 125 (H2 02); liquefied petroleum gases containing particulates 04_C3' Gasolines containing at least 780 compounds having boiling points between 30 and 220 °C (standard ration point); sometimes separating into light gasoline, known as LON (light naphtha cracked 0), and into heavy gasoline, known as HON (heavy cracked naphtha); a light distillate known as LCO (light cycle oil) containing at least 780 compounds having boiling points between 220°C and 360°C;

— 9 2 — A heavy distillate sometimes known as HCO (heavy cycle oil) containing at least 780 compounds having a boiling point between 360°C and 440°C; Optionally a residue or slurry that is generally purified from the catalyst particles it contains for at least compounds having an LST boiling point of 440"C. Here the term heavy cycle oil or HCO is used to designate any portion resulting from the FCC catalytic cracking stage ) or RFCC (d) and containing at least 780 compounds having a boiling point higher than 360 "residue. It is understood that this lot may undergo lead particle separation stage e catalytic cracking throughput separation unit Separation of Jolie Fracturing (gall) as dale on primary separation of ingots; strip for compression and fractionation of gases and also distillation for fractionation of different liquid rations. This type of fractionation unit is well known to one skilled in the art. Stage E allows for separation of ingots Resulting from the catalytic cracking stage (d) obtaining at least one cu portion of a light gas with a standard boiling range between 220 and 360°C (LCO) 5 and at least one heavy portion with a boiling point greater than 360°C (HCO) These portions may be combined into fuel pools At least a portion of the LCO and/or HCO portions are combined into the fuel cu pool (specifically the bunker bunker of residual type ¢ produced during the mixing phase) 5 (. Optionally 'a portion of the LCO and/or HCO fractions may be recycled before the hydrometallurgy stage (0) and/or hydrotreatment stage (b). 0 Mixing stage (f) The mixing stage (3) is performed 2 a of the fraction resulting directly from the separation stage (=) consisting of a portion of a portion of the atmospheric residue type resulting from stage C and/or a portion of a portion of the vacuum residue;

Toy from another fraction comprising at least a portion of the LCO and/or HCO lots resulting from Separation Phase (E); for Cu) fuel; Specifically, bunker oil is of a retarded type. It is understood that 'Fuel ofl' means, in the invention, a hydrocrion fraction that can be used as fuel. It is understood that 'ay 'Fuel oil stock' in the invention; hydrocarbon fraction that forms; Mixed with stocks of coal fuel oil. Optionally other fuel oil stocks from (kerosene share or cu share) gas from separation stage (C) may be incorporated; For example) or process outflow stocks (kerosene, direct-distilled vacuum distillate gas oil, or conversion process flow stock) into the fuel oil. According to the invention; Beneficially controlling flows makes it possible to reduce 0 contribution of expensive flow stocks. The use of flux stocks of external origin to the process during the blending phase represents (f) generally less than 710 wt. of fuel oil; Less than 75 wt. cu of fuel is preferred. According to a very favorable form, the use of shares of external origin does not occur for the operation. The present invention aims to improve the properties (cu) of fuels by controlling the properties and flows of various stocks. It is possible to control the characteristics precisely by means of the 5 operating conditions of the different segments. It is possible to control the flows precisely by the operating conditions during the productions but also by the separation phases and then chal by the mixing phase. This improvement specifically includes consolidation; During the mixing stage og) a portion of the atmospheric residue and/or the vacuum residue resulting from the separation stage (c). Since these rations were obtained after hydrotreating; Its sulfur content is low and it contains saturated particles giving ua 0 combustion properties that will compensate for the addition of aromatic LCO and/or HCO rations. LCO and/or HCO rations do not have good combustion properties but are not too sticky; Hence, it is widely used for its flow properties to reduce the viscosity of the mixture. The amount of LCO and 4060 available on dag in particular depends on the amount of feedstock from the catalytic cracking stage and therefore indirectly on the quantities of atmospheric residue and/or vacuum residue not subject to catalytic cracking

— 1 3 — and sent directly to the mixing stage (5 of) This is made possible by specific bodies for the separation stage (2) specified above. According to a very preferred form the separation stage (c) is carried out under specific conditions that make it possible to improve the aromatic index COAL by directing the atmospheric residue and/or vacuum residue fractions to the catalytic cracking stage (3) and/or mixing stage (3). The CCA values are calculated according to the ISO 8217 standard using the equation: [Ig(v) = 0.85)] and 81-1411 — m = CCAI T+273 F.1 1 483 ( ) " ) 3 2 3 4 where: 1 0 is temperature; expressed in decantation; where is the viscosity kinematic; v is the kinematic viscosity at temperature 7 expressed in milliliters aye per second; 5 is the density at 15 “methods” expressed in kilograms per cubic meter; a is the decimal logarithm. Thus, in the absence of vacuum distillation, the This directive makes it possible for the atmospheric residue 5 fraction of the hydrotreated hydrotreated directly to the mixing stage (F) to represent between 740 and 795 wt., preferably between 745 and 790 wt., of the fuel oil formed in the mixing stage (F). Unreleased to the mixing stage (f) to the catalytic cracking stage (d). similarly; in a scheme involving vacuum distillation and where there is no routing of the hydrotreated atmospheric residue fraction to the mixing stage (f); This directive shall make it possible for the vacuum hydrotreated residue 0 fraction released directly to the mixing stage (f) to represent between 740 7190 preferably between 750 and 785 by weight” of the fuel oil formed in the mixing stage (f). The remaining unreleased atmospheric residue is sent to the mixing stage (f) to the catalytic cracking stage (d) as a mixture

— 2 3 — with at least a portion and preferably all of the vacuum distillate from the hydrotreatment stage (b). Wal This residual vacuum residue released to the catalytic cracking stage (d) is not obtained by vacuum distillation but forms gia from the atmospheric residue fraction released directly to the catalytic cracking stage (d). In a scheme including vacuum distillation (Rasy) from simultaneous routing of the atmospheric residue fraction and the vacuum residue fraction to the mixing phase (and); the dia of the sum of the atmospheric residue and vacuum residue fractions shall be between 795 ,740 preferably between 85 745 oJ wt ; of cu) the fuel formed in the mixing stage (f). 0 Examples The atmospheric tailings of the Arab Medium type (see Table 1) are subjected to a hydrotreating phase for the tailings (see Table 2). Table 1: Characteristics of intermediate feedstock (AR all = 0 7 - f Siar) Table 2: Operating conditions of the tailings hydrotreating stage CoMoNi HDM catalyst on alumina CoMoNi transition catalyst on alumina

Weighted average temperature to start the session | 370

These conditions make it possible to achieve hydrodesulfurization of the feedstock by about 793 (HDS). The throughput resulting from the dalled stage is analyzed with hydrogen to determine the yields of different products and the different lots (Table 3).

Table 3: Hydrotreating phase yields

— 4 3 — Vacuum Distillate (350- 4525200) 40.51 sale Vacuum Residue (2552004) 45.71 Atmospheric Residue (4535004) 86.22 (Jal) To continue, reference will be made to Figure 1 shown above; which uses numbering to locate flows and provide residues The flow produced from the hydrotreating stage (7) is subjected to a separation stage (C) according to different alternative forms.The flow (7) is sent to multiple separators (SEP) 5 operating at pressures and temperature levels different temperatures which make it possible to separate the gas fraction (23) ¢ containing hydrogen and light hydrocrions; and the liquid fraction (25). This liquid fraction (25) undergoes atmospheric distillation (ADU) for the recovery of atmospheric distillates (AD) 24) and a portion of atmospheric residue type AR (9). Depending on the alternative forms, the atmospheric residue portion may pass to catalytic cracking (d) via line (11) and/or to the mixing stage (f) via line 0 (12) and/or to vacuum distillation (VDU) via line (26). ) and a portion of vacuum residue type VR (10) destined for catalytic cracking (d) via line (13) and/or mixing stage (f) via line (14). The separation stage (e) allows the separation of the waste (16) resulting from the catalytic cracking stage (d) into different products (not represented; specifically LPG and gasoline) Mg light share oil LCO and heavy share oil HCO are represented Combined destined LCO (19) 4 Combined destined HCO (20) But there may also be surpluses from these quotas that are not assimilated. The mixing stage allows obtaining FO (1 2) fuel cu) having a target viscosity of 80 3 cst at 50°C by mixing at least one AR (12) at least 0 and/ or one VR lot (14) with LCO lot (19) and/or HCO lot (20) and/or EXT out-of-process flow stock (22) where in these examples is sale marine distillate edo has a viscosity of 2.6 cst at Marine Gas Oil (MGO) density of 850 kg/m³ and a sulfur content of 70.096 wt. Flows are presented; expressed as 7 wt. Attached to the feedstock (feedstock flow = 100(¢) of the process (at the inlet of hydrotreating) for different cases (see Table 4).

Table 4: Material flows according to different conditions (7 by weight / feedstock)

flow 26 11 12 10

No

Case AR|« AR|« AR AR + 0 no VR|«— m aa aa ah ah ah ah ah ah i count with we] ah wo] a a a a a a a a a a a ا ا ا ا ا ا ا ا ا ا ۛ ہ ا ا ا To ا in - A Hm Fc Fd En -

A (em) is not in front of EN - [ee] mo] ee EN L is affiliated with Table 4 stream 13 14 19 20 22 21 AH AH

FO|« a )aggress + 00+ LCO|«VR +- VR case TE <2) a] 60# after ms =] 0 22) a] on] after me ww) # ro] a] mr ah 8 t 5 ou] 3 em] mr ah 5 om] em] mr ah

—_ 3 7 —_

’ ’ | ’ : 9 | ’ 1 SS 032 a) Mr 974 SS 9 ’ | ا

in case '8; The entire atmospheric waste stream is sent to vacuum distillation and vacuum distilled. The vacuum distillate flow (8) and the vacuum tailings flow (13) are sent to catalytic cracking. These two streams are thus able to remain united in the tailings shape

aerial; Then back to case 8.

Thus 8 and 8 QUES of Cus are leftovers at the output of the unit; Even if the diagrams for the class stage are different. similarly; Alternative forms of separating phase composition (e) exist in all of the cases presented.

It is possible ¢ starting from the streams of Table 4 to determine the composition of fuel butyrate (21)” ie, Sins for each

0 Component (12) (14) (19) (20) and (22) introduced in the mixing stage (f); expressed as a percentage by weight of the Lad component relative to fuel oil (21). Table 5: Composition of fuel butter (7 wt.) Condition | | FO| “—EXT| +00 “LCO —VR —AR (5) (5) (5) (5) (5)

M and uh uh uh uh uh uh uh uh uh uh uh uh uh uh uh uh uh uh

The characteristics of fuel oils (21) obtained according to different conditions are shown in the following table: Table 6: Characteristics of fuel oils (flow (21))

density at | viscosity at | CCA sulfur (7).

5 centigrade (kg / 50 centigrade)

(sie | (nS) meters

RMG380 1 max | 380 max | 870 max | 0.5 max a

For cases (A 8; 8; © and `0); the objective is to maximize the CCA of the fuel oil (21) by optimizing the amount of vacuum residue VR that goes directly to the mixing stage ( (f) (14). CCAI increases when (miss) VR (14) in fuel oil for LCO fraction (19) and HCO fraction (20): fuel oil CCAl © > fuel oil CCAI 8 > A/00 Fuel Oil A

however; Density (cw) of the fuel exceeds the maximum value of grade (RMG380) so it is necessary to add a small amount of marine distillate MGO (22) in order to reduce the density; but also the viscosity decreases; a quality higher than the minimum is obtained Specifications for fuel oil '0. Therefore, an ideal content for VR (14) is between 740 and 790; preferably

be between 750 and 7285 by weight; in fuel oil (21).

Cases 00 D' and 0 (comparison) comply with prior art; That is, formation of arrangements of hydrotreated tailings followed by catalytic cracking for fully hydrotreated AR (11). The resulting 00 fuel oil has a sulfur content greater than 70.5. Furthermore it; The resulting fuel oils contain very high proportions of HCO 5 (19) LCO (20), which is reflected in very low viscosities; high densities and therefore high CCAI values. It is approximately 718 of the distillate

5 Marine MGO (22) is necessary in fuel oil '0a in order to bring CCAI below 870 and approximately 8 marine distillate MGO (22) is necessary in fuel oil 'D' for CCAI Jaa Ji of 850. These blends do not improve flows well; they lead to the introduction of high amounts of marine distillate (MGO) (22), which greatly increases the production cost (cw) of the fuel (21).

in case ]; There is a lot of AR going to (d) AR ie going to (f) forming

0 mixture without contributing to flow out of the process. viscosity exceeds 380 cst at *50°C; The resulting fuel oil cannot be refined according to Grade 41//6380A. The case '] is aimed at reducing the resulting viscosity in the case by adding the marine distillate (MGO) so that it does not exceed 380 cstoke at 00 km/h. It is necessary that the fuel (cu) comprise 75.6 of the distillate MGO La

For cases «GF 4a | f', the goal is CCAl sal) to maximize fuel oil (21) by optimizing the amount of AR that goes directly to the mixing stage (f) (12). 1/00 increases when the AR (12) in fuel oil of LCO ration (19) and HCO ration (20) decreases: FUEL A/066 cu F > CCAI fuel oil © > Fuel oil A/060 H. However, the density of the fuel oil exceeds the maximum value of grade RMG380, so it is necessary to add a large amount of marine distillate MGO (22) in order to reduce the density, but the viscosity also decreases. A quality higher than the minimum specification is obtained for obtaining fuel oil 'A. Thus, there is an ideal content for atmospheric residue AR (12) that ranges between 740 and 795, preferably between 90 5 745 by weight' in the oil. fuel (21).

When comparing case E and case A, it is seen that by decreasing the amount of AR going directly to

mixing phase (f); The viscosity decreases and becomes according to RMG380 grade

Claims (1)

Claims 1- A process for converting a heavy hydrocarbon feedstock containing at least a hydrocarbon fraction having a sulfur content of at least 70.1 by weight” and a metals content of at least 10 ppm; an initial boiling point of at least 0°C and a final boiling point of at least 600°C; the process includes the following stages: (a) The hydrodemetallization stage is optional in interchangeable reactors; Where the stage of the hydrocarbon feedstock is in contact with hydrogen via a hydrodemetallization catalyst. 0 (b) dallas stage hydrotreating for a stable bottom of the throughput resulting from the hydrodemetallization stage (a) Le The last stage or hydrocarbon feedstock is carried out in contact with hydrogen and the processing catalyst Hydrotreatment (c) Separation of the bypass resulting from the hydrotreating stage (b) comprising a gas/liquid separation followed by atmospheric distillation which allows obtaining at least one portion of a residue type (go> (d) a catalytic cracking stage of a section of an atmospheric residue type share resulting from stage (c); (2) a catalytic cracking inflow phase (d) that makes it possible to obtain at least one Cu) light gas portion with a standard boiling range between 220 and 360"C; referred to as the cu) light cycle (LCO) Light Cycle Oil and at least one heavy share of “((HCO) Heavy Cycle Oil i) boiling point greater than 360”C; referred to as ZBT cycle’s share of atmospheric residue type resulting from stage (2) with at least a section and mixing stage ( 5) Gases with a standard boiling range between 220 and 360 "CW"; referred to as Cycle Oil (cw) and Heavy Duty with a boiling point greater than 360 "Cw; referred to as Light Cycle Oil (LCO) (2) Which results from the separation phase (HCO) Heavy Cycle Oil (Cu) referred to as — 3 4 — For a fuel oil for use as marine fuel with a sulfur content SUIfUr less than or equal by weight and an aromatic index (CCAl) calculated ig of ISO 8217; in an amount less than 870; representing the said portion of the quota Atmospheric residue type between 740 955 lbs by weight (Cu) of fuel produced. 5 Wy dad -2 of Cus] Aled). The hydrodemetallization stage (a) is carried out at a temperature between 300°C and 500°C; And under absolute pressure between 5 MPa and 35 MPa” with a vacuum velocity for the hydrocarbon feedstock HSV within a range of 0.1 hours*-1 to 5 hours”-1 and the amount of hydrogen mixed with crude 0 feeding between 100 and 5000 standard cubic meters (Sm3) standard cubic meters per jie cubic meter (M3) cubic meter of liquid feedstock. 3. The process pursuant to claim 2; Where the hydrotreating stage is carried out at a temperature of Bla between 300°C and 500°C; Under absolute pressure between 5 and 35 MPa 5 MPa” with a vacuum velocity of chydrocarbon feedstock commonly known as HSV within the range of 0.1 hours*-1 to 5 hours*-1 and with an amount of 0017 hydrogen mixed with the feedstock between 100 and 5000 jis Standard cubic meters (5013) per cubic meter (M3) cubic meter of liquid feedstock. 0 4- The process according to claim 3 where the catalytic cracking stage is carried out in at least one reactor operating as a descending or ascending reactor containing a catalytic cracking catalyst; Operates with a catalyst to feedstock ratio of between 4 and 15 ¢ and with an outlet temperature of the reactor(s) between 450 and 6000"C. 5 5- The operation according to the protection element of where it is added; in the mixing phase (and); cu) stock of at least one DAT fuel selected from a kerosene lot or cu) gas from the separation phase (c) An external process flow stock selected from “le cu kerosene” a direct-distilled vacuum distillate or a process flow stock resulting from the conversion process. 6. The process pursuant to claim 5; Where the flow stock fraction is less than 710 wt. of (5 cu) fuel output, less than 75 wt. cu. of fuel output is preferred. 7- The process according to Claim 6, where the hydrocarbon feedstock can be selected from atmospheric residues; direct vacuum distillation residues; crude oils; cut crude oils; de-asphalt resins; asphalt or asphalt tar; dail residues from conversion operations “0 aromatic extracts from lines for the production of lubricant stocks”; Bituminous sands or Jib (glide cus) or its derivatives; oils of rock origin or their derivatives taken alone or as a mixture. Empty residues, or mixtures thereof. 9- Process according to claim 8 Gua The hydrotreating stage (b) comprises a first hydrodemetallization (HDM) stage (b1) conducted in one or more hydrodemetallization zones in the bottoms of stationary where the throughput stage is from stage (a); or feedstock and hydrogen in the absence of phase 0 (); in contact with a hydrodemetallization catalyst and a subsequent second hydrodesulfurization (HDS) stage (B2) conducted in one or more hydrodesulfurization zones in still beds; Where the throughput stage is from the first hydrodemetallization stage (B1) in contact with the hydrodesulfurization catalyst -hydrodesulfurization 25 0 The process according to claim 9 wherein the hydrotreating stage (b) comprises a first hydrodemetallization (HDM) stage (b1) conducted in one or more hydrodemetallization zones in fixed bottoms; where the throughput stage is from stage (a); or feedstock and hydrogen in the absence of phase ( ) in contact with the hydrodemetallization catalyst a second subsequent transition phase (B2) conducted in one or more transition zones in still beds; where the throughput stage of the first hydrodemetallization (B1) is in contact with a transition catalyst; and a third subsequent hydrodesulfurization (HDS) stage (b3) conducted in one or more hydrodesulfurization zones in the Cus dnl 0 bottoms the throughput stage of dls je second transition (b2) is in contact with Hydrodesulfurization catalyst 1- The process of claim 10. where the resulting fuel oil shows a sulfur content of less than or equal to 70.1 by weight. From 991 kg / m3 and viscosity at 50 "C by less than 380 cStoke. 6 4 ¥ < Fm AE my any rE TT aaa ++ tn EE EE : i k 3 "ss Tig] lal ; ov Yh (b) ex ipa haba 50 3 enamel) 11 0 yr foes 2 Joie ¥ ;J § Sls 3 ofa MA oo Xs (3) zh 5 th A = tipi 3: only 5 ths: a gy (UE: may ye ye ye ye ye ye ye ye ye ye ye ye ye ye ye ha) List yg e and vn ion cm sine for sale fig. 1 The Saudi Authority for Intellectual Property Sweden Authority for Intellectual Property pW RE .¥ + \ A 0 § Um 5 + < Ne ge “Benaj > Aye Ki Jada Li Days TEE Bbha Nase eg + Ed - 2 - 3 .++ .* provided that the annual financial fee is paid for the patent and that it is not null and void due to its violation of any of the provisions of the patent system, layout designs of integrated circuits, plant varieties and industrial designs or its implementing regulations. »> Issued by + BB 0.B Saudi Authority for Intellectual Property > > > “+ PO Box 1011 .| for ria 1*1 uo ; Kingdom | Arabic | For Saudi Arabia, SAIP@SAIP.GOV.SA