EP1199347A1 - Procede de raffinage de petrol brut - Google Patents

Procede de raffinage de petrol brut Download PDF

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Publication number
EP1199347A1
EP1199347A1 EP00925681A EP00925681A EP1199347A1 EP 1199347 A1 EP1199347 A1 EP 1199347A1 EP 00925681 A EP00925681 A EP 00925681A EP 00925681 A EP00925681 A EP 00925681A EP 1199347 A1 EP1199347 A1 EP 1199347A1
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EP
European Patent Office
Prior art keywords
oil
distillation
crude oil
thermal cracking
separating
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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.)
Granted
Application number
EP00925681A
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German (de)
English (en)
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EP1199347A4 (fr
EP1199347B1 (fr
Inventor
Shin-ichi Chiyoda Corp. SHIMIZU
Masamichi Chiyoda Corp. TAMURA
Yukitaka Chiyoda Corp. WADA
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Chiyoda Corp
Chiyoda Chemical Engineering and Construction Co Ltd
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Chiyoda Corp
Chiyoda Chemical Engineering and Construction Co Ltd
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Publication of EP1199347A1 publication Critical patent/EP1199347A1/fr
Publication of EP1199347A4 publication Critical patent/EP1199347A4/fr
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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
    • C10G9/00—Thermal non-catalytic cracking, in the absence of hydrogen, of hydrocarbon oils
    • 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
    • C10G55/00—Treatment of hydrocarbon oils, in the absence of hydrogen, by at least one refining process and at least one cracking process
    • C10G55/02—Treatment of hydrocarbon oils, in the absence of hydrogen, by at least one refining process and at least one cracking process plural serial stages only

Definitions

  • the present invention relates to a method of treating a crude oil, which particularly comprises, as an essential part, a so-called upgrading method of a heavy oil, where a heavy oil content contained in a crude oil is converted into a light fraction in refining of petroleum for producing value-added petroleum products from a crude oil.
  • a crude oil 2 received by a refinery and subjected to a prescribed pretreatment is separated by distillation in an atmospheric distillation apparatus 100 to afford, downward from the top of the column, a gas content 101, a kerosene content 103, a gas oil content 105, and the like as each distillate, whereby a heavy oil content 107 is separated at the bottom of the column as a residual oil.
  • the gas content 101 withdrawn from the top of the column is further separated into, for example, a light, gas content (H 2 , C 1 , C 2 ) 111, an LPG content (C 3 , C 4 ) 113, a C 5 -C 6 content 115, a naphtha content 117 in a gas recovery section 110.
  • hydrogen sulfide is individually removed from the light gas content 111 and the LPG content 113 as well as the C 5 -C 6 content 115 by means of a washing apparatus, and the light gas content 111 is used for a fuel of its own consumption, and the LPG content 113 is for an LPG product.
  • the C 5 -C 6 content 115 is used as a balancing agent for gasoline.
  • the naphtha content 117 is generally subjected to a treatment for removing sulfur contents and nitrogen contents by a hydrorefining apparatus 120, followed by catalytic reformation in a reforming apparatus 125 to enhance an octane value in order to form a balancing agent for gasoline.
  • the kerosene content 103 is subjected to hydrodesulfurization and refining by a hydrorefining apparatus 130 (comprising a desulfurizing and cracking reactor R1 and a rectification part D1) to remove sulfur contents, nitrogen contents, etc., and is generally used as a kerosene product or a jet fuel.
  • a hydrorefining apparatus 130 comprising a desulfurizing and cracking reactor R1 and a rectification part D1 to remove sulfur contents, nitrogen contents, etc.
  • the gas oil content 105 is also subjected to hydrodesulfurization and refining by means of a hydrorefining apparatus 140 (comprising a desulfurizing and cracking reactor R2 and a rectification part D2) to remove sulfur contents, etc., and is generally used as a diesel gas oil.
  • a hydrorefining apparatus 140 comprising a desulfurizing and cracking reactor R2 and a rectification part D2 to remove sulfur contents, etc., and is generally used as a diesel gas oil.
  • the heavy oil content 107 withdrawn from the column bottom of an atmospheric distillation apparatus 100 is transferred to a vacuum distillation apparatus 200 in order to subject to a so-called upgrading treatment which converts it into a light fraction.
  • the heavy oil content 107 is separated into a vacuum gas oil 201 and a vacuum residue 205.
  • the vacuum residue is dealt with a raw material for thermal cracking.
  • the vacuum gas oil 201 is subjected to desulfurization, cracking, and refining and separation by means of a hydrogenating apparatus 210 (comprising a desulfurizing and cracking reactor R3 and a rectification part D3).
  • Each fraction separated (separated into naphtha, kerosene, diesel gas oil, vacuum gas oil at the rectification part D3) is usually transferred to the above-mentioned gas recovery section 110 or combined with each line of the products such as kerosene and diesel gas oil to form products as illustrated in the drawing.
  • the vacuum residue 205 separated by means of the vacuum distillation apparatus 200 is fed to a thermal cracking section 220 (comprising a reactor R4 and a rectification part D4).
  • a raw material for thermal cracking is thermally cracked to form thermal cracking products such as cracked gas and cracked oil, and residues such as pitch and coke.
  • the thermally cracked oil is further subjected to secondary treatments such as hydrorefining, hydrocracking, catalytic cracking, and separation to form final products.
  • secondary treatments of the thermally cracked oil it is generally mixed with the kerosene content 103, the gas oil content 105, the vacuum gas oil fraction 201 separated in the atmospheric distillation apparatus 100 and the vacuum distillation apparatus 200 in advance. Therefore, in order to adjust to their boiling point ranges, the thermally cracked oil is further separated according to plural boiling point ranges at the rectification part (D4).
  • the present invention is contrived under the above circumstances, and object thereof is to provide a method of treating a crude oil capable of improving the complexity of conventional constitution of the apparatus, simplifying the process and saving the space, and thereby reducing a cost for the treatment.
  • the object is to provide a method of treating a crude oil also applicable to a small-scale refining of petroleum.
  • the present invention provides a method of treating a crude oil comprising:
  • the distilling section in which said step of separating the crude oil by distillation and step of separating the thermal cracking product by distillation carried out at the same time comprises a pre-separation apparatus and a main separation apparatus.
  • the heavy oil content separated in said distilling section and withdrawn from the bottom amounts 15 to 55 parts by weight relative to 100 parts by weight of a distillate oil from the distilling section.
  • the heavy oil content separated at said step of separating the crude oil, withdrawn from the bottom, and fed to the step of thermal cracking contains substantially neither gas oil content nor vacuum gas oil content.
  • no heavy oil content is contained in thermal cracking residue at said step of thermal cracking.
  • the distillate oil separated at the step of separating the crude oil by distillation and the step of separating the thermal cracking product by distillation carried out at the same time in said distilling section is collectively subjected to desulfurization, cracking, and hydrogenation treatment in identical one hydrotreating section.
  • crude oil received by a refinery is permitted to stand in a crude oil tank, and water and sludge content are removed by means of desalter.
  • the crude oil 2 subjected to such pretreatment is, as a preferred embodiment of the present invention, introduced into a distilling section 10.
  • Figure 2 illustrates a preferred detailed flowchart of the distilling section 10.
  • the crude oil 2 is first introduced into a pre-separating apparatus, for example, a simple flash vessel 3 and then separated into a gas content 3a and a liquid fraction 3b.
  • the liquid fraction 3b is introduced into a vacuum distillation apparatus 10', and then separated into an extract oil 11a extracted from the upper part of the column and a vacuum residue which is a heavy oil content 15 from the bottom of the column (the step of separating crude oil by distillation).
  • the gas content 3a from the flash vessel 3 is cooled and further separated into a gas content 12 and a liquid fraction 11b.
  • the liquid fraction 11b is mixed with the extract oil 11a from the vacuum distillation apparatus 10' to form a raw material oil for hydrotreating (distillate oil) 11.
  • the distillate oil 11 contains a vacuum gas oil content, a gas oil content, a kerosene content, and a naphtha content, while the gas content 12 contains an LPG (liquified Petroleum gas) content, a light gas content and the like.
  • LPG liquid Petroleum gas
  • Preferred conditions for operating the distilling section 10 including the vacuum distillation apparatus 10' are as follows: a pressure of about 1 to 10 kPa and a temperature of about 350 to 400°C. Furthermore, separation ratio of the vacuum residue (15) to the distillate oil 11 in the distilling section 10 is made 15 to 55 parts by weight relative to 100 parts by weight of the distillate oil 11. The separation ratio is determined according to kind of oil. For example, in the case of Arabian heavy crude oil, the vacuum residue (15) is preferably made 45 to 55 parts.
  • the crude oil to be fed to the distilling section 10 may be an ultra-heavy crude oil such as oil sand bitumen from Canada and Orinoco tar from Venezuela.
  • separating ratio of the distillate oil 11 and the vacuum residue (15) in the distilling section 10 may be preferably adjusted so that suitable raw material can be fed to the thermal cracking section and the hydrotreating section.
  • the crude oil to be fed to the distilling section 10 may be an atmospheric distillation residue, and, in this case, the separating ratio may be again adjusted as mentioned above.
  • the process is operated so that the heavy oil content 15 contains substantially neither gas oil content nor vacuum gas oil content.
  • the operation of the step for separating the crude oil by distillation is carried out so that the gas oil content and the vacuum gas oil content are withdrawn at the line of said distillate oil 11.
  • substantially direct introduction of the crude oil 2 to the distilling section 10 including the vacuum distillation apparatus 10' enables to fulfill the purposes of adjusting vacuum residue oil that is a raw material oil for the thermal cracking section, and adjusting a mixed oil composed of naphtha, kerosene, gas oil and vacuum gas oil, that is a raw material oil for collective hydrotreating section. Accordingly, since it is not necessary to separate the crude oil into each fraction of naphtha, kerosene, gas oil and vacuum gas oil by distillation, the conventional large-scale atmospheric distillation apparatuses become unnecessary.
  • the heavy oil content 15 (vacuum residue (15)) separated at such step of separating a crude oil by distillation where the distilling section 10 is used and obtained substantially from the bottom of the distilling section 10 is introduced to the thermal cracking section 20, in which the heavy oil content 15 is thermally cracked and separated into a lightened thermal cracking product 21 and a thermal cracking residue 25 (the step of thermal cracking).
  • first characteristic of the present invention is to carry out said step of separating a crude oil by distillation and step of separating a thermal cracking product by distillation in identical one distilling section 10 at the same time, and feed a suitable raw material oil to the thermal cracking section and feed a suitable raw material oil to the hydrotreating section.
  • the thermal cracking section 20 is operated so that the thermal cracking residue 25 at the step of thermal cracking contains no heavy oil content.
  • the raw material for thermal cracking is generally pre-heated or, in some cases, pre-cracked at a tube-type heating furnace, followed by further thermal cracking by means of a reactor of vessel-type (EUREKA, delayed coker) or fluid bed-type (flexicoker, fluid coker) to form thermal cracking products such as a cracked gas and a cracked oil, and residues such as pitch and coke, which are separated from each other.
  • a reactor of vessel-type EUREKA, delayed coker
  • fluid bed-type flexicoker, fluid coker
  • thermal cracking step of the present invention although hitherto known various thermal cracking sections can be used, use of a so-called EUREKA is particularly preferable in view of the combination of downstream hydrotreating step.
  • EUREKA process is a process which generally produces gas, cracked oil and pitch by thermal cracking of a vacuum residue oil.
  • the detail is shown in "Specification of Japanese Patent Publication No. 15795/1982", “Thermal and Nuclear Power Generation (Karyoku Genshiryoku Hatsuden)", Vol. 36, No. 2, pp. 151-166 (1985), “Proceedings of 17th Panel Discussion on the Petroleum Refining, Petroleum Society (Sekiyu Gakkai Dai 17 Kai Seisei Paneru Touronkai Kaigiroku)", pp. 93-102 (1992), “Catalysts in Petroleum Refining and Petrochemical Industries 1995", pp.
  • the reaction system of EUREKA process adopts a semi-batch method combining a tube-type cracking furnace and a vessel-type reactor, and thereby aims to cope with both production of thermo-melting pitch which has a property of homogeneous and of narrow in distribution of reaction residence time and economy of the process.
  • the reactor is composed of two pieces of apparatus per 1 set and charge of the raw material is switched alternatively at about 90 minutes intervals by means of an automatic switching valve.
  • the cracked oil has a characteristic that it contains less polycondensate molecules as compared with the product of other cracking apparatus.
  • the polycondensate molecules are present in the raw material oil, severer conditions are required in downstream desulfurization, cracking, or hydrogenation.
  • the distillate oil 11 separated in the distilling section 10 contains a vacuum gas oil content, a gas oil content, a kerosene content, a naphtha content and the like. These contents are collectively introduced to identical one hydrotreating section 30 without separating into each content having prescribed boiling range, where they are collectively subjected to desulfurization, cracking, and hydrogenation treatment. Since the thermally cracked oil formed at the thermal cracking step contains unsaturated hydrocarbons, quality of the oil is unsettled without further treatment. Therefore, hydrotreating is necessarily conducted in order to saturate them with hydrogen for purpose of the settlement.
  • the thermally cracked oil is, in general, separated into each fraction by rectification and, after each fraction is mixed with each distillate oil such as naphtha, kerosene, gas oil, or vacuum gas oil, each fraction is individually subjected to hydrorefining.
  • each distillate oil such as naphtha, kerosene, gas oil, or vacuum gas oil
  • each fraction is individually subjected to hydrorefining.
  • the pressure is usually set up so as to increase as the fraction of a raw material oil changes from light one to heavy one in the case that the thermal cracking of the residual oil is not carried out.
  • the pressure is set up high even for a light oil and therefore, the pressure at hydrorefining tends to flat throughout the treatment of from a light fraction to a heavy fraction.
  • the pressure for hydrorefining ranges 500 to 3000 kPaG for naphtha, 1000 to 4000 kPaG for kerosene, 4000 to 7000 kPaG for gas oil, or 5000 to 7000 kPaG for vacuum gas oil, typically 2000 to 3000 kPaG for naphtha and kerosene, 5000 kPaG for gas oil, or 6000 kPaG for vacuum gas oil.
  • the pressure for hydrorefining of each fraction of naphtha, kerosene, gas oil, or vacuum gas oil is set up typically the same level, i.e., 6000 kPaG. Accordingly, in the refining scheme incorporating the thermal cracking of the residual oil, there are low technical necessity of individual hydrorefining and high technical rationality of collective hydrotreating.
  • the collective hydrotreatment in the present invention is different from that of the case not accompanying the residual oil cracking (for example, the specification of Japanese Patent Application Laid-Open No. 82573/1995 etc.) in the technical background, and is a peculiar technique in the thermal cracking scheme of the residual oil.
  • the collective hydrotreating in the present invention is different from the general technique of collective hydrotreating of the distillate oil from a crude oil, and is characterized by the technical and economical significances found in the integration with the thermal cracking of residual oil.
  • the reaction style is not particularly limited, and can include various embodiments such as fixed bed, fluid bed, moving bed, and the like.
  • the composition unnecessary to treat in the hydrotreating section 30 is excluded from the compositions for collective treatment.
  • the refined oil 31 collectively subjected to desulfurization, cracking and hydrogenation treatment in the hydrotreating section 30 is a synthetic crude oil of low sulfur content containing no vacuum residual oil fraction and having high added value, and is treated in the downstream refining scheme according to a conventional technique.
  • the present invention aims to simplify whole process and reduce a cost for the treatment by collectively subjecting the distillate oil 11 including the refined product after thermal cracking to desulfurization, cracking, and hydrogenation treatment, and also collectively operating the separation by distillation after said treatment.
  • Part of the lightened thermal cracking product 21 may be transferred to the hydrotreating section 30 without returning to the distilling section 10.
  • the distilling section 10 to which the crude oil 2 is introduced may comprise a pre-separating apparatus and a main separating apparatus as a preferable partially transformed example.
  • the pre-separating apparatus include a flash vessel, a simple distilling column, and the like
  • examples of the main separating apparatus include a vacuum distilling apparatus. Since a part of vacuum gas oil can be also separated, the placement of the pre-separating apparatus in advance affords a merit that sizes of the heating furnace and the vacuum distilling tower can be reduced.
  • the flash vessel is a more preferable embodiment than the distilling column.
  • the reasons are as follows: the treatment in the downstream hydrotreating section 30 is carried out collectively, and thus, more precise separation is not only technically unnecessary but also economically undesirable.
  • Reaction tower temperature 340 to 380°C
  • Example 1 operating conditions in the hydrotreating section 30 was changed as described in the following. Except for those points, an experiment of refining a crude oil was conducted as described in Example 1.
  • Reaction tower temperature 340 to 380°C
  • the present invention provides a method of treating a crude oil comprising a step of separating the crude oil by distillation where the crude oil is separated by distillation into a distillate oil and a heavy oil content, a step of thermal cracking where the heavy oil content separated at said step of separating the crude oil by distillation and obtained substantially from the bottom is thermally cracked to lighten the content, and a step of separating the thermal cracking product by distillation where the thermal cracking product obtained by lightening at said step of thermal cracking is separated by distillation; wherein said step of separating the crude oil by distillation and said step of separating the thermal cracking product by distillation are carried out at the same time in a distilling section comprising a vacuum distillation apparatus.
  • the distillate oil separated at the step of separating the crude oil by distillation and the step of separating the thermal cracking product by distillation, which are carried out at the same time in said distilling section is collectively subjected to desulfurization, cracking, and hydrogenation treatment in identical one hydrotreating section to produce a synthetic crude oil of low sulfur content containing no vacuum residual oil fraction and having high added value, followed by treatment in the downstream refining scheme according to a conventional technique. Accordingly, it is possible to simplify the process and save the space, and thereby to reduce a cost for the treatment.
  • the method is also applicable to a small-scale refining of petroleum.
  • the method of treating a crude oil according to the present invention is especially utilized as a so-called upgrading method of a heavy oil, which converts a heavy oil content contained in a crude oil into a light oil fraction in refining of petroleum producing value-added petroleum products from a crude oil.

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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)
  • Physics & Mathematics (AREA)
  • Thermal Sciences (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
EP00925681A 1999-05-17 2000-05-16 Procede de raffinage de petrol brut Expired - Lifetime EP1199347B1 (fr)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
JP13548199 1999-05-17
JP13548199 1999-05-17
PCT/JP2000/003125 WO2000069992A1 (fr) 1999-05-17 2000-05-16 Procede de raffinage de petrol brut

Publications (3)

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EP1199347A1 true EP1199347A1 (fr) 2002-04-24
EP1199347A4 EP1199347A4 (fr) 2003-05-02
EP1199347B1 EP1199347B1 (fr) 2004-12-15

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EP00925681A Expired - Lifetime EP1199347B1 (fr) 1999-05-17 2000-05-16 Procede de raffinage de petrol brut

Country Status (5)

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EP (1) EP1199347B1 (fr)
JP (1) JP4564176B2 (fr)
CN (1) CN100419046C (fr)
DE (1) DE60016755T2 (fr)
WO (1) WO2000069992A1 (fr)

Families Citing this family (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN100441666C (zh) * 2006-09-01 2008-12-10 周斌 获取高质量生物柴油的方法
KR100933308B1 (ko) * 2009-03-17 2009-12-22 재원산업 주식회사 기회원유의 정제장치 및 방법
CN101962568A (zh) * 2010-10-19 2011-02-02 中海沥青股份有限公司 一种用于石油沥青生产的降蜡方法
RU2490307C1 (ru) * 2012-10-01 2013-08-20 Андрей Владиславович Курочкин Способ переработки нефти
RU2495084C1 (ru) * 2012-11-27 2013-10-10 Андрей Владиславович Курочкин Способ переработки нефти
RU2515938C1 (ru) * 2013-04-24 2014-05-20 Андрей Владиславович Курочкин Способ переработки нефти
RU2707188C2 (ru) * 2016-03-17 2019-11-25 Андрей Владиславович Курочкин Установка безостаточной переработки нефти

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB748427A (en) * 1953-09-10 1956-05-02 Exxon Research Engineering Co A combination process for fractionating, cracking and coking petroleum hydrocarbons
US4432941A (en) * 1980-10-13 1984-02-21 Peter Spencer Apparatus for the distillation and thermal cracking of a crude oil feedstock and a reactor for use therein
US4441989A (en) * 1981-11-03 1984-04-10 Peter Spencer Process and apparatus for thermal cracking and fractionation of hydrocarbons
US4454023A (en) * 1983-03-23 1984-06-12 Alberta Oil Sands Technology & Research Authority Process for upgrading a heavy viscous hydrocarbon
WO1996026992A1 (fr) * 1995-03-02 1996-09-06 Shell Internationale Research Maatschappij B.V. Procede de conversion d'une huile hydrocarbure

Family Cites Families (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3487006A (en) * 1968-03-21 1969-12-30 Lummus Co Direct pyrolysis of non-condensed gas oil fraction
FR2504936B1 (fr) * 1981-04-29 1985-08-09 Raffinage Cie Francaise Procede d'obtention d'un petrole brut synthetique

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB748427A (en) * 1953-09-10 1956-05-02 Exxon Research Engineering Co A combination process for fractionating, cracking and coking petroleum hydrocarbons
US4432941A (en) * 1980-10-13 1984-02-21 Peter Spencer Apparatus for the distillation and thermal cracking of a crude oil feedstock and a reactor for use therein
US4441989A (en) * 1981-11-03 1984-04-10 Peter Spencer Process and apparatus for thermal cracking and fractionation of hydrocarbons
US4454023A (en) * 1983-03-23 1984-06-12 Alberta Oil Sands Technology & Research Authority Process for upgrading a heavy viscous hydrocarbon
WO1996026992A1 (fr) * 1995-03-02 1996-09-06 Shell Internationale Research Maatschappij B.V. Procede de conversion d'une huile hydrocarbure

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
See also references of WO0069992A1 *

Also Published As

Publication number Publication date
DE60016755D1 (de) 2005-01-20
JP4564176B2 (ja) 2010-10-20
WO2000069992A1 (fr) 2000-11-23
DE60016755T2 (de) 2005-12-01
EP1199347A4 (fr) 2003-05-02
CN1351643A (zh) 2002-05-29
CN100419046C (zh) 2008-09-17
EP1199347B1 (fr) 2004-12-15

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