EP1120454A2 - Verfahren zur Verminderung des Schwefelgehaltes und von polyaromatischen Kohlenwasserstoffen in Kohlenwasserstoff-Einsätzen - Google Patents

Verfahren zur Verminderung des Schwefelgehaltes und von polyaromatischen Kohlenwasserstoffen in Kohlenwasserstoff-Einsätzen Download PDF

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Publication number
EP1120454A2
EP1120454A2 EP01100726A EP01100726A EP1120454A2 EP 1120454 A2 EP1120454 A2 EP 1120454A2 EP 01100726 A EP01100726 A EP 01100726A EP 01100726 A EP01100726 A EP 01100726A EP 1120454 A2 EP1120454 A2 EP 1120454A2
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EP
European Patent Office
Prior art keywords
hydrotreating
catalyst
fcc
reactor
temperature
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.)
Withdrawn
Application number
EP01100726A
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English (en)
French (fr)
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EP1120454A3 (de
Inventor
Per Zeuthen
Barry H. Cooper
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Topsoe AS
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Haldor Topsoe AS
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Application filed by Haldor Topsoe AS filed Critical Haldor Topsoe AS
Publication of EP1120454A2 publication Critical patent/EP1120454A2/de
Publication of EP1120454A3 publication Critical patent/EP1120454A3/de
Withdrawn legal-status Critical Current

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    • 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
    • C10G65/00—Treatment of hydrocarbon oils by two or more hydrotreatment processes only
    • C10G65/02—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only
    • C10G65/04—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only including only refining steps
    • C10G65/08—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only including only refining steps at least one step being a hydrogenation of the aromatic hydrocarbons
    • 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
    • C10G65/00—Treatment of hydrocarbon oils by two or more hydrotreatment processes only
    • C10G65/02—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only
    • C10G65/04—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only including only refining steps
    • C10G65/043—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only including only refining steps at least one step being a change in the structural skeleton

Definitions

  • the present invention relates to a process for removal of sulphur and polyaromatic compounds in vacuum gas oil by hydrotreatment of FCC hydrocarbon feed stock.
  • FCC fluid catalytic cracking
  • Treating the FCC products involves multiple process solutions: naphtha treating, light-cycle oil (LCO) treating and flue gas treating to control the SO x emissions.
  • Treating feed to the FCC unit can increase yields and at the same time lower sulphur levels in gasoline, and diesel fuels and reduces SO x emissions.
  • the increased conversion in the FCC unit resulting from feed treatment may improve refinery margins.
  • Product treatment offers no yield benefits.
  • a general object of the invention to improve production of a FCC feed being substantially reduced in content of sulphur and nitrogen compounds and in particular having a low content of polyaromatic hydrocarbons and thereby improved crackability and conversion and selectivity in the FCC unit.
  • Hydrotreatment of FCC feed substantially reduces sulphur content of gasoline, light (LCO), and decant oil. It also lowers the amount of sulphur in spent catalyst coke, which results in the reduction of SO x emissions from the regenerator.
  • LCO light
  • hydrotreating can be used to achieve a high level of desulphurization (>90%) and greatly reduce the sulphur content of the FCC products. High severity desulphurization would be needed to reduce coke sulphur to the near zero level.
  • Nitrogen compounds poison the active sites in the FCC catalyst and increase coke-making propensity of the catalyst and reduce the yield of valuable products. Nitrogen removal by hydrotreatment is much harder than sulphur removal. Moderate to high severity is generally required to achieve a high denitrogenation level (>70%).
  • PAH Poly-aromatic hydrocarbons
  • Di-aromatic species distribute in all liquid products from the FCC and also convert to coke on the FCC catalyst. Triaromatic and tetra-aromatic species either convert to coke on the catalyst or distribute in the light cycle oil or heavier fraction from the FCC. Maximising FCC gasoline and lighter valuable products requires an understanding of how to maximise the conversion of multiple ring aromatic species (di+) to single (mono) aromatic or saturated ring species in the FCC feed hydrotreater.
  • the degree of aromatic saturation is highly dependent on hydrogen partial pressure, catalyst type and the space velocity of the hydrotreater.
  • the kinetic and thermodynamic responses of sulphur, nitrogen and other contaminant removal are such that an increase in temperature results in conversion of these contaminants.
  • the kinetic responses for these contaminants represent irreversible reactions.
  • Typical conditions for a FCC pre-treatment reactor are hydrogen pressure of 40-120 bar; average reactor temperature 350-410°C; liquid hourly space velocity (LHSV) of 0.5-2.5 m 3 oil/m 3 catalyst/h.
  • LHSV liquid hourly space velocity
  • the end of the run is normally reached when the design temperature for the reactor is reached, which is decided by the metallurgy of the reactor.
  • the run length is a very important consideration.
  • a shorter run length means high costs due to a higher rate of catalyst replacement, and relative more downtime (i.e. time off-stream) for catalyst change-out with a resultant loss of revenue due to reduced production of high quality FCC gasoline products.
  • the aromatic saturation will pass through a maximum as the reaction temperature is increased.
  • the maximum is identified as the point, where the net rate of aromatic saturation is zero due to the effects of the forward and reverse reactions.
  • the temperature at which the PAH equilibrium is met will depend on a number of factors including hydrogen pressure, feed PAH content and composition and LHSV.
  • the general object of the invention to provide a process for the production of a low sulphur and nitrogen FCC feed with a low content of polyaromatic hydrocarbons and thereby increase the FCC yields and in particular the FCC gasoline production.
  • the present invention is a process for reducing content of sulphur compounds and poly-aromatic hydrocarbons in a hydrocarbon feed stock having a boiling range between 200°C and 600°C, which process comprises the steps of:
  • the inventive process a low PAH content is achieved in FCC feeds with only slight additional investment in reactor volume and without reduction in run length.
  • the essences of the inventive process consists of cooling the effluent exiting the hydrotreating reactor and passing the cooled product through a small posttreat reactor containing a suitable catalyst.
  • the PAH content of the product existing in the hydrotreating reactor is reduced in the posttreatment reactor owing to the more favourable equilibrium conditions at the lower temperature. Consequently, the end of run temperature in the main hydrotreating reactor is not limited by the PAH content of the product exiting the main reactor, and a small overall reactor volume (main hydrotreater plus post treat reactor) is required for a given run length.
  • the final bed of the main hydrotreating reactor is operated at lower temperature instead of using a post treatment reactor.
  • the process can be used to lower the content of poly-aromatic hydrocarbons and thereby improve the performance of the FCC unit because of improved crackability of the FCC feed as well as the FCC product qualities.
  • the petroleum vacuum distillates used in the present invention boil in the range 400-650°C and have a PAH content in the range 5-50 wt%.
  • Examples of petroleum fractions include straight run vacuum gas oils from a vacuum crude distillation and vacuum fractions of the product from fluid catalytic cracking and thermal cracking processes including cooking and mixtures thereof. The process is particularly suitable for blends of vacuum distillates containing thermal cracked oils and FCC products because these oils generally have a high PAH content.
  • Feedstock is mixed with hydrogen, heated in the furnace 1 and passed through the hydrotreating reactor 2.
  • the effluent from the hydrotreater is cooled to a suitable temperature by heat exchange with the feed to hydrotreater 3 or by other means before passing to post-treatment reactor 4.
  • the temperature employed in the post-treatment reactor will typically be in the range of 300°C to 375°C, and will typically be at least 50°C lower than the outlet temperature of the hydrotreater.
  • the LHSV in the posttreatment reactor will typically be in the range 2-20 m 3 oil/m 3 catalyst/h and the total pressure will be at the same level as that in the hydrotreating reactor.
  • the catalyst used in the hydrotreating reactor may be any catalyst used for hydrotreating petroleum fractions and known in the art.
  • the catalyst contains at least one metal on a porous refractory inorganic oxide support. Examples of metals having hydrotreating activity include metals from groups VI-B and VIII e.g. Co, Mo, Ni, W, Fe with mixtures of Co-Mo, Ni-Mo and Ni-W preferred.
  • the metals are employed as oxides or sulphides.
  • porous material suitable as support include alumina, silica-alumina, alumina-titania, natural and synthetic molecular sieves and mixtures hereof with the alumina and silica-alumina being preferred.
  • the catalyst used in the posttreatment reactor may be any catalyst used for hydrotreating vacuum distillate streams.
  • Preferred catalysts are Ni-Mo, Co-Mo and Ni-W on alumina.
  • the active metal on the catalyst may be either presulphided or in-situ sulphide prior to use by conventional means.
  • the hydrotreating reactor section may consist of one or more reactors. Each reactor may have one or more catalyst beds.
  • the function of the hydrotreating reactor is primarily to reduce product sulphur, nitrogen, CCR and metals. Owing to the exothermic nature of the desulphurisation reaction, the outlet temperature is generally higher than the inlet temperature. Some reduction of PAH may be achieved in the hydrotreating reactor especially at start of run conditions. As the catalyst activity declines due to the deactivation by carbonaceous deposits, sintering of the active phase and other mechanisms, the inlet temperature to the hydrotreating reactor is raised, resulting in an increased outlet temperature.
  • the function of the post-treatment reactor is primarily to reduce the PAH content, but also to lower the sulphur and nitrogen.
  • the reduction in PAH will result in a reduction in the product oil density and refractive index (RI) both of which are desirable. Also reduction in the sulphur and nitrogen content will be achieved at the conditions in the post-treatment reactor.
  • RI refractive index
  • Feedstock A (Table 1) was hydrotreated in a semi-adiabatic pilot plant unit running with an outlet temperature of 405°C - a temperature, which normally is considered as end of run temperature (EOR) conditions and LHSV at 1 (hr -1 ). The pressure was 50 bar. Pure hydrogen was used as gas.
  • Feedstock A is a mixture of 50% cooker gas oil and 50% straight run vacuum gas oil (SR VGO).
  • Feedstock B (Table 1) was hydrotreated at typical FCC pretreatment conditions in a pilot plant unit at temperature at 400°C (inlet) - 420°C (outlet) temperature, which normally is considered as end of run conditions at LHSV at 1.7 (h -1 ). The pressure was 50 bar.
  • the feedstock was a pure cracked VGO.
  • Product A contains 14,5 wt% PAH, which would be typical for a product obtained at EOR conditions in a unit where the hydrogen partial inlet pressure is 50 bar, if the feedstock contains more cracked feedstock or DAO (De-Asphalt Oil) the contents will be higher.
  • DAO De-Asphalt Oil
  • Product B contains 35,2 wt% PAH, which is rather high, but typical for cracked feedstocks.
  • Product A from Example 1 is further hydrotreated at lower temperatures at high LHSV.
  • the pressure is 50 bar, which is identical to the pressure at which product A was obtained.
  • Example 2 Temperature (°C) LHSV (h -1 ) SG 60/60 S (wt%) N (wt ppm) Di-aromatics (wt%) Triaromatics (wt%) PAH (wt%) 325 6 0,8914 0,0038 505 4,6 5,0 9,6 350 6 0,8911 0,0029 468 4,9 4,9 9,5

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  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Engineering & Computer Science (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
  • Catalysts (AREA)
  • Liquid Carbonaceous Fuels (AREA)
EP01100726A 2000-01-25 2001-01-12 Verfahren zur Verminderung des Schwefelgehaltes und von polyaromatischen Kohlenwasserstoffen in Kohlenwasserstoff-Einsätzen Withdrawn EP1120454A3 (de)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
DKPA200000118 2000-01-25
DK200000118 2000-01-25

Publications (2)

Publication Number Publication Date
EP1120454A2 true EP1120454A2 (de) 2001-08-01
EP1120454A3 EP1120454A3 (de) 2002-01-30

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Family Applications (2)

Application Number Title Priority Date Filing Date
EP01100722A Withdrawn EP1120453A3 (de) 2000-01-25 2001-01-12 Verfahren zur Verminderung des Schwefelgehaltes und von polyaromatischen Kohlenwasserstoffen in Destillatbrennstoff
EP01100726A Withdrawn EP1120454A3 (de) 2000-01-25 2001-01-12 Verfahren zur Verminderung des Schwefelgehaltes und von polyaromatischen Kohlenwasserstoffen in Kohlenwasserstoff-Einsätzen

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EP01100722A Withdrawn EP1120453A3 (de) 2000-01-25 2001-01-12 Verfahren zur Verminderung des Schwefelgehaltes und von polyaromatischen Kohlenwasserstoffen in Destillatbrennstoff

Country Status (8)

Country Link
US (3) US20020117425A1 (de)
EP (2) EP1120453A3 (de)
JP (2) JP2001207177A (de)
CN (2) CN1224674C (de)
CA (2) CA2332262A1 (de)
NO (2) NO20010419L (de)
RU (1) RU2250917C2 (de)
ZA (2) ZA200100724B (de)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP1925654A1 (de) * 2006-11-22 2008-05-28 Haldor Topsoe A/S Verfahren zur katalytischen Wasserstoffbehandlung von siliziumhaltigen Kohlenwasserstoffeinsätzen

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US7776205B2 (en) * 2004-04-22 2010-08-17 Exxonmobil Research And Engineering Company Process to upgrade hydrocarbonaceous feedstreams
US7780845B2 (en) * 2004-04-22 2010-08-24 Exxonmobil Research And Engineering Company Process to manufacture low sulfur distillates
CA2593533C (en) * 2005-01-14 2012-07-10 Exxonmobil Chemical Patents Inc. Ultra pure fluids
FR2917423B1 (fr) * 2007-06-12 2012-11-30 Inst Francais Du Petrole Hydrotraitement en deux etapes d'une charge issue d'une source renouvelable mettant en oeuvre un premier catalyseur metallique et un deuxieme catalyseur sulfure
CN101250435B (zh) * 2008-03-31 2011-07-20 中国石油化工集团公司 一种烃类加氢转化方法
KR101503069B1 (ko) * 2008-10-17 2015-03-17 에스케이이노베이션 주식회사 유동층 접촉 분해 공정의 경질 사이클 오일로부터 고부가 방향족 및 올레핀을 제조하는 방법
EP2199371A1 (de) 2008-12-15 2010-06-23 Total Raffinage Marketing Verfahren zur aromatischen Hydrierung und Erhöhung des Cetangehalts von Ausgangsmaterialien aus dem Mitteldestillat
IT1396948B1 (it) 2009-12-16 2012-12-20 Italghisa S P A Pasta elettrodica per elettrodi in grafite privi di "binder" a base idrocarburica
JP5535845B2 (ja) 2010-09-14 2014-07-02 Ｊｘ日鉱日石エネルギー株式会社 芳香族炭化水素の製造方法
CN102757819B (zh) * 2011-04-29 2015-02-25 中国石油化工股份有限公司 一种由催化裂化重油生产高辛烷值汽油的方法
CN103827268B (zh) 2011-07-29 2016-05-18 沙特阿拉伯石油公司 选择性中间馏分加氢处理方法
EP2737030A1 (de) * 2011-07-29 2014-06-04 Saudi Arabian Oil Company Integriertes selektives hydrocracking und verfahren für fluidkatalytisches cracking
US8911514B2 (en) * 2011-12-15 2014-12-16 Uop Llc Hydrotreating methods and hydrotreating systems
US10273420B2 (en) 2014-10-27 2019-04-30 Uop Llc Process for hydrotreating a hydrocarbons stream
US20170335207A1 (en) * 2016-05-17 2017-11-23 Exxonmobil Research And Engineering Company Jet and diesel selective hydrocracking
CN106221785B (zh) * 2016-09-30 2017-12-19 中国石油大学(华东) 一种利用稠油原生金属卟啉催化多环芳烃加氢的方法
US10604709B2 (en) 2017-02-12 2020-03-31 Magēmā Technology LLC Multi-stage device and process for production of a low sulfur heavy marine fuel oil from distressed heavy fuel oil materials
US20180230389A1 (en) 2017-02-12 2018-08-16 Magēmā Technology, LLC Multi-Stage Process and Device for Reducing Environmental Contaminates in Heavy Marine Fuel Oil
US12025435B2 (en) 2017-02-12 2024-07-02 Magēmã Technology LLC Multi-stage device and process for production of a low sulfur heavy marine fuel oil
US12071592B2 (en) 2017-02-12 2024-08-27 Magēmā Technology LLC Multi-stage process and device utilizing structured catalyst beds and reactive distillation for the production of a low sulfur heavy marine fuel oil
US11788017B2 (en) 2017-02-12 2023-10-17 Magëmã Technology LLC Multi-stage process and device for reducing environmental contaminants in heavy marine fuel oil
CN110832056B (zh) * 2017-07-04 2022-02-15 三菱化学株式会社 芳香族烃的制造方法

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GB824635A (en) * 1958-07-08 1959-12-02 Exxon Research Engineering Co Process for improving kerosenes and diesel fuels
GB940290A (en) * 1961-04-28 1963-10-30 Universal Oil Prod Co Process for the hydrorefining of aromatic hydrocarbon distillates
FR1359910A (fr) * 1963-03-22 1964-04-30 Charbonnages De France Hydrocarbures cyclaniques et leur procédé d'obtention
DE2935191A1 (de) * 1979-08-31 1981-04-02 Metallgesellschaft Ag, 6000 Frankfurt Verfahren zur gewinnung von dieseloel
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Publication number Priority date Publication date Assignee Title
EP1925654A1 (de) * 2006-11-22 2008-05-28 Haldor Topsoe A/S Verfahren zur katalytischen Wasserstoffbehandlung von siliziumhaltigen Kohlenwasserstoffeinsätzen
US7713408B2 (en) * 2006-11-22 2010-05-11 Haldor Topsoe A/S Process for the catalytic hydrotreating of silicon containing hydrocarbon feed stock
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Publication number Publication date
NO20010419L (no) 2001-07-26
EP1120453A2 (de) 2001-08-01
CN1309163A (zh) 2001-08-22
CN1311289A (zh) 2001-09-05
NO20010418D0 (no) 2001-01-24
EP1120453A3 (de) 2002-01-30
JP2001207177A (ja) 2001-07-31
US20050133411A1 (en) 2005-06-23
NO20010418L (no) 2001-07-26
CN1224674C (zh) 2005-10-26
CA2332157A1 (en) 2001-07-25
RU2250917C2 (ru) 2005-04-27
EP1120454A3 (de) 2002-01-30
CA2332262A1 (en) 2001-07-25
ZA200100725B (en) 2001-11-06
JP2001207178A (ja) 2001-07-31
US20010013484A1 (en) 2001-08-16
ZA200100724B (en) 2001-11-06
US20020117425A1 (en) 2002-08-29
NO20010419D0 (no) 2001-01-24

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