US3862898A - Process for the production of olefinically unsaturated hydrocarbons - Google Patents

Process for the production of olefinically unsaturated hydrocarbons Download PDF

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Publication number
US3862898A
US3862898A US383620A US38362073A US3862898A US 3862898 A US3862898 A US 3862898A US 383620 A US383620 A US 383620A US 38362073 A US38362073 A US 38362073A US 3862898 A US3862898 A US 3862898A
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United States
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zone
cracking
olefinically unsaturated
high pressure
unsaturated hydrocarbons
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US383620A
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English (en)
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Harold B Boyd
James R Lambrix
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MW Kellogg Co
Pullman Inc
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Pullman Inc
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Priority to US383620A priority Critical patent/US3862898A/en
Priority to JP48141158A priority patent/JPS5037704A/ja
Priority to GB1135474A priority patent/GB1463392A/en
Priority to CA195,475A priority patent/CA1013773A/en
Priority to FR7412728A priority patent/FR2239518B1/fr
Priority to NL7405264A priority patent/NL7405264A/nl
Priority to DE2419436A priority patent/DE2419436A1/de
Priority to IN1046/CAL/1974A priority patent/IN144320B/en
Priority to AR253966A priority patent/AR214162A1/es
Priority to ES426794A priority patent/ES426794A1/es
Priority to TR18059A priority patent/TR18059A/xx
Priority to BR4967/74A priority patent/BR7404967A/pt
Priority to AU71226/74A priority patent/AU482942B2/en
Priority to BE146701A priority patent/BE817818A/xx
Priority to SE7409669A priority patent/SE391530B/xx
Priority to DK404774A priority patent/DK404774A/da
Priority to AT620374A priority patent/AT340554B/de
Priority to NO742749A priority patent/NO742749L/no
Priority to SU742063546A priority patent/SU650512A3/ru
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Publication of US3862898A publication Critical patent/US3862898A/en
Assigned to M. W. KELLOGG, THE reassignment M. W. KELLOGG, THE ASSIGNMENT OF ASSIGNORS INTEREST. Assignors: M.W. KELLOGG COMPANY, THE
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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
    • C10G51/00—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more cracking processes only
    • C10G51/02—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more cracking processes only plural serial stages only
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
    • C10G2400/20—C2-C4 olefins

Definitions

  • This invention relates to the integration of fluid catalytic cracking of heavy hydrocarbon oils containing petroleum residuum and thermal pyrolysis of hydrocarbons to produce olefmically unsaturated hydrocarbons such as ethylene and propylene.
  • a heavy hydrocarbon containing petroleum residuum is converted to cracked products including naphtha in a heavy oil cracking unit having a fluid catalytic cracking zone and a catalyst regenreration zone.
  • the naphtha is passed to a noncatalytic thermal pyrolysis zone and converted to thermally cracked effluent containing large quantities of olefins having from 2 to 4 carbon atoms.
  • the olefins are recovered in a known manner by process gas compression and refrigeration.
  • high pressure steam is produced in the regeneration zone of the heavy oil cracking unit and the steam so produced is utilized in olefins recovery.
  • HOC heavy oil cracking
  • FIG. 2 is a schematic diagram of a petrochemical refinery and discloses the production of C -C 4 olefins and aromatic compounds from crude petroleum oil wherein a substantial part of the thermal pyrolysis feed is derived from a residue fraction: of the crude oil.
  • FIG. 3 is a schematic diagram of steam generation and use within the petrochemical refinery concept of FIG. 2 and discloses a total energy concept with fulfillment of the entire gas compression energy requirements of the process through internal process generation of steam with consequent fuel and power savings.
  • a hydrocarbon feedstock containing petroleum residuum is introduced to the catalytic cracking zone 1 of a heavy oil cracking (HOC) unit.
  • the feedstock may be whole crude petroleum oil, topped petroleum crude, residue containing fractions from petroleum refining steps such as visbreaking, solvent deasphalting, hydrodesulfurization, and vacuum distillation but is preferably residuum boiling above about 600F that has been derived from atmospheric distillation of crude petroleum oill.
  • Such crude oil may contain from 0.1 to 8 weight percent sulfur, from 1 to 1,000 ppm organometallic compounds such as compounds of vanadium and nickel, and asphaltenes ranging from about 0.1 to about 20 volume percent. Wher asphaltene content is high, the residue fraction may undergo deasphalting or deasphaltening prior to further processing.
  • the heavy oil cracking (HOC) unit comprises a fluid catalytic cracking zone 1 and a catalyst regeneration zone 2.
  • Fluidized cracking catalyst circulating between the two zones may be of conventional type such as activated clay, silica-alumina, silica-zirconia, and aluminaboria, however, natural and synthetic zeolitic catalysts, particularly of the molecular sieve, matrix type having an average particle size range of from about 40 to about 100 microns, are preferred cracking catalysts.
  • the catalytic cracking zone 1 is. preferably a transfer line reactor and is most preferably a riser reactor of the type described in US. Pat. No. 3,607,127.
  • the riser type unit is more fully depicted in FIG. 2 of the drawmgs.
  • residue containing hydrocarbon feedstock is fed to the lower part of the riser reactor at a temperature of from about 150F to about 750F and is admixed with the cracking catalyst in the presence of fluidizing steam.
  • Typical cracking conditions include a temperature range: from about 850F to about 1,200F, pressure from about 10 psig. to about 50 psig., catalyst to oil ratio of from about 3:1 to 15:1, and space velocity of from about 0.5 to 1,000. Normally from 50 to percent of the cracking reaction takes place in the riser reactor with the remainder occurring in the disengaging and stripping zones located generally in the upper part of the heavy oil cracking unit.
  • Cracked effluent including a cracked naphtha fraction leaving the riser reactor disengages from catalyst in the upper part of the HOC unit and exits through a series of cyclone separators that. return entrained catalyst to a fluid bed regeneration zone belowthe disengaging zone.
  • Severe cracking conditions are employed in order to maximize conversion of the feedstock to naphtha boiling range hydrocarbons for thermal pyrolysis feed.
  • at least 65 volume percent and most preferably 80 to percent of the feed is cracked to light hydrocarbons boiling in the naphtha range, gases including hydrogen, cycle oil, and coke.
  • stripping zone is fitted with suitable baffling and steam sparging means to strip occluded cracked effluent which passes over head while catalyst coated with coke and some non-volatile hydrocarbons passes downwardly into regeneration zone 2 located in the lower part of the I-IOC unit.
  • an oxygen-containing gas preferably air
  • Air furnished by this blower will normally be at a pressure of from about 20 psia. to about 70 psia. and delivered at a rate of from about I 1 pounds to about 13 pounds per pound of coke burned from the catalyst.
  • the air delivery rate is varied in order to maintain regeneration zone temperatures of from about l,000F to about l,400F and at which temperature materials coated on the catalyst are burned off to desired levels of residual coke on regenerated catalyst.
  • Such levels will generally be from about 0.05 to about 0.4 weight percent, preferably from about 0.05 to about 0.15 weight percent.
  • catalyst is returned to the riser reactor.
  • High pressure steam so produced is utilized in expansion turbine drives shown generally be reference numeral 3 employed in gas compression required for olefins recovery.
  • the quantity of high pressure steam from the regeneration zone of the HOC unit is sufficient to provide at least a major part of the gas compression energy requirements of the process and will generally provide about two-thirds of this requirement in terms of the weight flow rate of steam generated and expanded in compressor turbine drives.
  • gas compression energy is intended to mean the total energy expended in compressing pyrolysis effluent gas to the pressure required for olefins recovery in addition to te refrigeration compression required for chilling pyrolysis effluent in order to perform product separations by fractionation.
  • the compression energy required for these purposes will be about equally divided between process gas compression and refrigeration compression.
  • High pressure steam may drive turbo-generators and indirectly provide such gas compression energy requirements through electromechanical means, however, direct steam turbine drives to the compressors will generally be preferred.
  • a major part of the steam expanded through the turbines is condensed and recycled through a boiler feed water system.
  • a portion of this steam is further expanded to reduced pressure ranging from about I psia. to about 200 pisa. for use as steam diluent of hydrocarbon feed to thermal pyrolysis zone 4.
  • a cracked naphtha fraction separated from catalytically cracked effluent leaving the HOC until may be passed directly to thermal pyrolysis zone 5, however, the fraction will normally contain 'olefinic materials that tend to form coke and to polymerize excessively when subjected to pyrolytic conversion.
  • the cracked naphtha fraction is hydrotreated, as will be later described.
  • the cracked naphtha fraction is then admixed with diluent steam from the expansion turbines and introduced to thermal pyrolysis zone 5 which will be subsequently discussed in connection with FIG. 2.
  • Thermally cracked effluent from the pyrolysis zone is then cooled and passed to process gas compression zone 6 and pressurized to from about 400 psia. to about 650 psia. to facilitate fractionation of products.
  • Separations of hydrogen, fuel gases, ethane, propane, mixed C compounds, and products including ethylene and propylene are than performed in product recovery zone 7 by known chilling and separation steps A typical separations process is described in the Nov. 13, 1965 issue of Chemical Week," 77-80.
  • the integrated process is carried out according to the following example- Referring now to FIG. 2, 690,000 lb./hr. of desalted whole petroleum crude oil contaihin g 26weight percent sulfur is introduced through line 25 to thermal distillation zone 26. A gaseous overhead fraction comprising predominantly C and C paraffmic hydrocarbons is removed through line 27. A straight-run naphtha fraction boiling between about F and about 450F is removed from the distillation zone through lines 28 and 34 and passed to thermal pyrolysis zone 35. A light gas oil fraction boiling in the range from about 300F to about 650F is also removed from the distillation zone and passed through lines 29 and 34 to pyrolysis zone 35.
  • a heavy gas oil fraction boiling in the range from about 550F to about l,000F is removed from a lower section of the distillation zone through line 30 and hydrodesulfurized in zone 31 with hydrogen introduced through line 32.
  • the hydrodesulfurizer may utilize cobalt-molybdenum or alumina catalyst and is operated at temperatures ranging from about 550F to 750F and pressure ranging from about 200 psia. to about 600 psia.
  • Desulfurized gas oil is then passed to the thermal pyrolysis zone through lines 33 and 34.
  • portions of the naphtha or gas oil fractions may be diverted to other uses, however, in an integrated petrochemical refinery of the type described herein, it is preferred to pass these fractions to the thermal pyrolysis zone in order to maximize olefins and aromatic hydrocarbons production.
  • all or part of the residue fraction from thermal distillation zone 26 may be passed through a solvent de asphalting zone, for example a propane deasphalting unit, to obtain a deasphalted oil which is subsequently charged to the HOC unit.
  • a solvent de asphalting zone for example a propane deasphalting unit
  • This step will generally not be used when asphaltene and metals content of the residue fraction is not excessively high.
  • the residuum fraction is fed to the lower part of riser 38 to a temperature of from about l50F to about 750F and is admixed with circulating, regenerated cracking catalyst and with fluidizing steam introduced from line 40 at about 100 psia.
  • Cracked effluent including a cracked naphtha fraction laeaving riser 38 disengages from the catalyst in disengaging zone 41 and passes upwardly through cyclones (not shown) for recovery through line 43.
  • Catalyst with coke and occluded hydrocarbons deposited thereon passes downwardly through the disengaging zone to stripping zone 42 for removal of occluded hydrocarbons which pass overhead with the cracked effluent. Stripped catalyst then passes to regeneration zone 44 where coke and non-volatile hydrocarbonaceous materials are burned from the catalyst with air introduced through line 45 from regenerator air blower 46. Flue gases containing carbon monoxide from the regeneration step leave zone 44 through line 47 for further use and treatment.
  • Heat produced during regeneration is removed by passing boiler feed water through line 50 to coils 51 located within the regeneration zone and thereby producing steam by indirect heat exchange at a high pressure of about 1,500 psia. which is removed at a rate of 650,000 llb./hr. through line 52.
  • Cracked effluent removed from the HOC unit through line 43 is introduced to cracker fractionator 53 at a temperature of about l,000F and pressure of about psia.
  • a volatitle overhead stream comprising hydrogen and paraffinic hydrocarbons lighter than C, is removed from the cracker fractionator through line 54.
  • C and lighter materials would be used as plant fuel or compressed and diverted to other process facilities.
  • the stream is combined with overhead in line 27 from thermal distillation zone 26 and integrated into olefins production as later described.
  • Decant oil is removed from the bottom of a cracker fractionator 53 through line 55 and is preferably passed to catalytic cracking zone 38 of the HOC unit through line 37. Alternately, all or a part of this oil may be diverted to other uses, for example, carbon black produc tion or auxiliary fuel. A cycle oil suitable for further processing to commercial fuel oil is removed by way of line 56.
  • a cracked naphtha fraction boiling between about 85F and about 450F is removed from the cracker fractionator through line 57 at the rate of 127,000 lb./hr. and passed to hydrotreating zone 58 for olefins saturation and desulfurization in the presence of a catalyst with hydrogen introduced to the hydrotreating zone.
  • hydrotreating zone 58 92,000 lb./hr. of pyrolysis gasoline from downstream process sources later described is passed to hydrotreatment zone 58 for similar processing.
  • Hydrotreating will serve to prepare the feed for pyrolytic conversion by saturating olefms, partially saturating aromatic compounds, and by removing sulfur contained in the fraction by hydrodesulfurization. A substantial part of the hydrogen required in hydrotreating may be obtained from the hydrogen produced in the HOC unit and later recovered in the product separation zone.
  • Hydrotreating is generally performed in one or more stages at temperatures ranging from about 450F to about 800F and pressures from about 100 psia. to 1,500 psia.
  • Preferred hydrotreating catalysts comprise one or more hydrogeneration metals supported on a suitable carrier material. Oxides or sulfides of molybdenum, tungsten, cobalt, nickel, and iron supported on such supports as alumina and silica-alumina are used. The most preferred catalysts are cobalt molybdate or alumina and nickel molybdate on alumina.
  • the catalyst can be employed in the form of a fixed bed or a fluidized bed. Liquid phase or mixed phase conditions can be used.
  • Space velocities are from about 1 to about 15 volumes of feed per volume of catalyst per hour and hydrogen addition rates are from about 50 to about 2,000 SCF/bbl.
  • a number of hydrogen treating processes of varying degrees of severity are disclosed in Hydrocarbon Processing, September 1972, pages -184.
  • a hydrotreated naphtha fraction containing predominantely C paraffinic hydrocarbons is recovered from the hydrotreating zone and passed through line 59 to thermal pyrolysis zone 35 at the rate of 35,000 lb./hr.
  • a hydrocarbon stream containing naphtha and aromatic compounds is also separated in hydrotreating zone 58 and passed through line 60 to an aromatics extraction and separation zone 61 which may typically utilize solvent extraction by, for example, ethylene glycol, furfural, or dimethyl formamide.
  • Proudct separations in extraction zone 61 yields 39,000 lb./hr. of benzene, 24,000 lb./hr. oftoluene, and 12,000 ]b./hr. of xylene. 104,000 lb./hr. of paraffiniic raffinate resulting from aromatics extraction is then passed through lines 62 and 59 to thermal pyrolysis zone 35.
  • Thermal pyrolysis zone 35 contains pyrolysis furnaces adapted fro steam cracking of hydrocarbons varying from light paraffms to gas oils to produce C to C olefins.
  • the thermal pyrolysis feed steams previously described are mixed with 310,000 lb./hr. of diluent steam from line 63 at a pressure of about 150 psia. Such steam is obtained from the discharge of gas compressor turbines as later described. Diluent ratios are about 0.6 pounds of steam per pound of naphtha feed, and 0.75 pounds of steam per pound of gas oil feed. It is understood that individual furnaces within the thermal pyrolysis zone may vary somewhat in detail design to suit the particular feed streams involved.
  • a pyrolysis furnace will contain convection heating coils in which feed materials are preheated to temperatures as high as l,200F and radiation sections in which preheated feed is converted to olefins in the presence of diluent steam at temperatures in the range of about l,400F to about 2,000f depending on the feedstock used and product mix desired.
  • Residence time of hydrocarbons in the furnaces is low, generally from about 0.2 seconds to about 2.0 seconds and maybe as low as 0.01 seconds.
  • Thermally cracked effluent containing C -C olefins, pyrolysis gasoline, pryrolysis oil, hydrogen, and light paraffms is passed from the thermal pyrolysis zone through line 64 to quench zone 65 where the effluent is rapidly cooled to a temperature of from about 600F to about 1,000F depending on the pyrolysis feedstock.
  • Boiler feed water is introduced to the quench zone and passed in indirect heat exchange with the thermally cracked effluent to produce 542,000 lb./hr. of steam at a pressure of about 1,500 psia. which is removed through line 66.
  • Thermally cracked effluent is passed from quench zone 65 through line 67 to effluent fractionator 68 where a pyrolysis oil bottoms fraction is removed and passed to the catalytic cracking zone 38 of the heavy oil cracking unit 39 at the rate of 43,000 lb./hr. through lines 69, 36, and 37.
  • An overhead fraction containing the oil-depleted thermally cracked effluent is recovered from the effluent fractionator through line 70 at a pressure of about 7 psig. and admixed with light hydrocarbons contained in lines 27 and 54.
  • the combined effluent stream is then passed through line 27 to a process gas compression zone 71 where pressure is increased from 7 psig. to 550 psia. in order to facilitate product separations.
  • a pyrolysis gasoline stream containing aromatic compounds, principally aromatic hydrocarbons such as benzene, toluene, and the xylenes, is separated from combined effluent in the gas compression zone 71 and passed through line 72 to previously described hydrotreating zone 58.
  • the combined effluent is passed through line 73 to acid gas separation zone 74 for removal of carbon dioxide and hydrogen sulfide, thence through line 75 to drying zone 76, and then through line 77 to chilling zone 78 where the effluent stream is cooled by refrigeration supplied from refrigeration compressors 79.
  • Hydrogen is removed from chilling zone 78 through line 80 at the rate of 7,000 lb./hr. This hydrogen is utilized in hydrotreating zone 58, hydrodesulfurization zone 31, and may be used for desulfurization of fuel oil separated in the cracker fractionactor 53.
  • Chilled pyrolysis effluent is then passed thro igl line 81 Ito product separation zone 82 where 152,000 lb./hr. of ethylene, 81,000 lb./hr. of propylene, and 91,000 lb./hr. of mixed C hydrocarbons are spearated by fractionation and removed as products of the process. Additionally, 38,000 lb./hr. of ethane and 14,000 lb./hr. of propane are removed from the product recovery zone and recycled via lines 83, 59, 33, and 34 to thermal pyrolysis zone 35. A residual stream of pyrolysis gasoline is also removed through line 84 and passed to hydrotreating zone 58.
  • FIG. 3 which illustrates steam integration with olefins production from crude oil
  • processing zones are those previously described for FIG. 2, however, many of the interconnecting process lines have been omitted for clarity.
  • flue gas produced from the oxidation of coke in the HOC unit regeneration zone will normally contain an appreciable amount of carbon monoxide, it is preferably passed to CO boiler 48 and burned with the aid of a high heat value fuel such as recovered fuel gas to generate high pressure steam from boiler feed water. All or part of the steam thus produced may be used in fulfilling the remaining energy requirements of the process, providing energy required by the regenerator air blower, or exported as a product of the 'process. Accordingly, 650,000 lb./hr. of 1,500 psia. steam is recovered from the CO boiler 48 and delivered through line 49 to high pressure steam header 85.
  • a high heat value fuel such as recovered fuel gas
  • High pressure steam is similarly passed from header through line 88 at the rate of 281,000 lb./hr. to refrigeration zone turbines 89 which are mechanically connected to closed loop refrigeration compressors shown generally by reference numeral 79. Steam exhausted from these turbines is also returned through line 92 to feed water recovery system 93.
  • a major portion of the steam entering turbin 91 is partially expanded to a medium pressure of about 450 psia. and passed through line 94 at the rate of 523,000 lb./hr. to medium pressure steam header 95. It is understood that an equivalent amount of steam expanded to the medium pressure may be exhausted from any of the high pressure steam turbines according to the specific conditions involved.
  • 210,000 lb./hr. of steam from header 95 is further reduced in pressure to about 150 psia. through valve 97 and combined with 100,000 lb./hr. of steam from line 98 that is produced at approximately the same pressure in cracker fractionator boiler 99 which removes heat from catalytically cracked effluent by recirculation of the fractionator bottom contents.
  • the combined stream is then passed through line 63 to thermal pyrolysis zone 35'for use as process diluent stream.
  • the remaining medium pressure steam is delivere through line 95 and 100 to other internal process uses such as pump drives, process heating, and fluidizing steam for the HOC unit.
  • the process embodiments of the present invention provide a means for the conversion of heavy hydrocarbons to olefins and aromatic compounds.
  • Whole crude oil and petroleum fractions containing substantial amounts of sulfur and metals can be converted to desirable products such as ethylene, propylene, benzene, toluene, and the xylenes.
  • the heavy oil cracking concept of the present invention is unique in that a residuum containing hydrocarbon may be converted and treated to a feedstock suitable for pyrolitic conversion to olefins in the presence of steam.
  • the embodiments of the invention are essentially selfsupporting from an energy balance standpoint.
  • the heavy oil cracking unit provides very large quantities of steam which are utilized to provide a major part of the gas compression energy requirements of the process. 1n the petrochemical refinery embodiment of the present invention, all of the internal gas compression energy and heat requirements of the process are furnished from the heavy oil cracking unit and the thermal pyrolysis quench zone and substantial quantities of high pressure steam are exported as a product of the process.
  • the feed to the heavy oil cracking unit may be recycled to extinction or a portion of the recycle material can be used as plant fuel.
  • the quantity of hydrogen required to saturate and desulfurize the various intermediate fractions produced in the preferred embodiments is much less than the quantity of hydrogen which would be required to support a hydrocracking unit and associated hydrodesulfurization units.
  • a process for the production of olefinically unsaturated hydrocarbons which comprises the steps of:
  • a hydrocarbon feedstock comprising petroleum residuum into the catalytic cracking zone of a heavy oil cracking unit in the presence of fluidized cracking catalyst at cracking conditions to produce a catalytically cracked effluent including a cracked naphtha fraction;
  • step (c) expanidng said high pressure steam from step (c) to provide at least part of the gas compression energy required for recovery of the olefinically unsaturated hydrocarbons;
  • An integrated process for the production of olefinically unsaturated hydrocarbons comprising the steps of:

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  • Oil, Petroleum & Natural Gas (AREA)
  • Engineering & Computer Science (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
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US383620A 1973-07-30 1973-07-30 Process for the production of olefinically unsaturated hydrocarbons Expired - Lifetime US3862898A (en)

Priority Applications (19)

Application Number Priority Date Filing Date Title
US383620A US3862898A (en) 1973-07-30 1973-07-30 Process for the production of olefinically unsaturated hydrocarbons
JP48141158A JPS5037704A (nl) 1973-07-30 1973-12-12
GB1135474A GB1463392A (en) 1973-07-30 1974-03-14 Process for the production of olefinically unsaturated hydro carbons
CA195,475A CA1013773A (en) 1973-07-30 1974-03-20 Process for the production of olefinically unsaturated hydrocarbons
FR7412728A FR2239518B1 (nl) 1973-07-30 1974-04-11
NL7405264A NL7405264A (nl) 1973-07-30 1974-04-18 Werkwijze voor het bereiden van olefinisch onverzadigde koolwaterstoffen.
DE2419436A DE2419436A1 (de) 1973-07-30 1974-04-23 Verfahren zur herstellung von olefinisch-ungesaettigten kohlenwasserstoffen
IN1046/CAL/1974A IN144320B (nl) 1973-07-30 1974-05-10
AR253966A AR214162A1 (es) 1973-07-30 1974-05-29 Un procedimiento para producir hidrocarburos olefinicamente in saturados
ES426794A ES426794A1 (es) 1973-07-30 1974-05-31 Procedimiento para la obtencion de hidrocarburos olefinica-mente insaturados.
TR18059A TR18059A (tr) 1973-07-30 1974-06-17 Olefinik olarak doymamis hidrokarbonlarin elde edilmesine mahsus usul
BR4967/74A BR7404967A (pt) 1973-07-30 1974-06-18 Processo para producao de hidrocarbonetos olefinicamente insaturados e processo integrado par a producao de hidrocarbonetos olefinicamente insaturados e de compostos aromaticos
AU71226/74A AU482942B2 (en) 1973-07-30 1974-07-15 Process forthe production of olefinically unsaturated hydrocarbons
BE146701A BE817818A (fr) 1973-07-30 1974-07-18 Procede pour la production d'hydrocarbures a insaturation olefinique
SE7409669A SE391530B (sv) 1973-07-30 1974-07-25 Forfarande for framstellning av olefiniskt omettade kolveten ur ett kolveteutgangsmaterial innefattande en petroleumrest genom fluidiserad katalytisk krackning samt efterfoljande termisk krackning
AT620374A AT340554B (de) 1973-07-30 1974-07-29 Verfahren zur herstellung von olefinisch ungesattigten kohlenwasserstoffen
DK404774A DK404774A (nl) 1973-07-30 1974-07-29
NO742749A NO742749L (nl) 1973-07-30 1974-07-29
SU742063546A SU650512A3 (ru) 1973-07-30 1974-09-20 Способ получени газообразных олефиновых углеводородов

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US383620A US3862898A (en) 1973-07-30 1973-07-30 Process for the production of olefinically unsaturated hydrocarbons

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JP (1) JPS5037704A (nl)
AR (1) AR214162A1 (nl)
AT (1) AT340554B (nl)
BE (1) BE817818A (nl)
BR (1) BR7404967A (nl)
CA (1) CA1013773A (nl)
DE (1) DE2419436A1 (nl)
DK (1) DK404774A (nl)
ES (1) ES426794A1 (nl)
FR (1) FR2239518B1 (nl)
GB (1) GB1463392A (nl)
IN (1) IN144320B (nl)
NL (1) NL7405264A (nl)
NO (1) NO742749L (nl)
SE (1) SE391530B (nl)
SU (1) SU650512A3 (nl)
TR (1) TR18059A (nl)

Cited By (34)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4009121A (en) * 1975-08-26 1977-02-22 Exxon Research And Engineering Company Method of temperature control in catalyst regeneration
US4064038A (en) * 1973-05-21 1977-12-20 Universal Oil Products Company Fluid catalytic cracking process for conversion of residual oils
US4143521A (en) * 1977-02-08 1979-03-13 Stone & Webster Engineering Corporation Process for the production of ethylene
US4162213A (en) * 1976-04-29 1979-07-24 Mobil Oil Corporation Catalytic cracking of metal-contaminated oils
US4176084A (en) * 1975-07-08 1979-11-27 Exxon Research & Engineering Co. Process for regenerating metal-contaminated hydrocarbon conversion catalysts
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WO1997034966A1 (en) * 1996-03-20 1997-09-25 Ormat Process Technologies, Inc. Solvent deasphalting unit and method for using the same
US6013852A (en) * 1997-11-21 2000-01-11 Shell Oil Company Producing light olefins from a contaminated liquid hydrocarbon stream by means of thermal cracking
US6033555A (en) * 1997-06-10 2000-03-07 Exxon Chemical Patents Inc. Sequential catalytic and thermal cracking for enhanced ethylene yield
US6303842B1 (en) 1997-10-15 2001-10-16 Equistar Chemicals, Lp Method of producing olefins from petroleum residua
US20060116543A1 (en) * 1999-07-07 2006-06-01 Naphtachimie S.A. & Bp Chemicals Limited Method and apparatus for steam cracking hydrocarbons
US20070029228A1 (en) * 2004-03-29 2007-02-08 Nippon Oil Corporation Hydrocracking catalyst and process for producing liquid hydrocarbon
US20070284285A1 (en) * 2006-06-09 2007-12-13 Terence Mitchell Stepanik Method of Upgrading a Heavy Oil Feedstock
US20100170828A1 (en) * 2006-03-30 2010-07-08 Nippon Oil Corporation Hydrocracking catalyst and process for producing fuel base material
US20120168348A1 (en) * 2010-12-29 2012-07-05 Coleman Steven T Process for cracking heavy hydrocarbon feed
US8658022B2 (en) 2010-11-23 2014-02-25 Equistar Chemicals, Lp Process for cracking heavy hydrocarbon feed
US8658019B2 (en) 2010-11-23 2014-02-25 Equistar Chemicals, Lp Process for cracking heavy hydrocarbon feed
US8663456B2 (en) 2010-11-23 2014-03-04 Equistar Chemicals, Lp Process for cracking heavy hydrocarbon feed
US8921633B2 (en) 2012-05-07 2014-12-30 Exxonmobil Chemical Patents Inc. Process for the production of xylenes and light olefins
US8937205B2 (en) 2012-05-07 2015-01-20 Exxonmobil Chemical Patents Inc. Process for the production of xylenes
US9181146B2 (en) 2010-12-10 2015-11-10 Exxonmobil Chemical Patents Inc. Process for the production of xylenes and light olefins
US9181147B2 (en) 2012-05-07 2015-11-10 Exxonmobil Chemical Patents Inc. Process for the production of xylenes and light olefins
US20180057758A1 (en) * 2016-08-24 2018-03-01 Saudi Arabian Oil Company Systems and methods for the conversion of feedstock hydrocarbons to petrochemical products
US10603657B2 (en) 2016-04-11 2020-03-31 Saudi Arabian Oil Company Nano-sized zeolite supported catalysts and methods for their production
CN111116292A (zh) * 2018-10-30 2020-05-08 中国石油化工股份有限公司 石油烃制备低碳烯烃的方法及装置
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US4064038A (en) * 1973-05-21 1977-12-20 Universal Oil Products Company Fluid catalytic cracking process for conversion of residual oils
US4176084A (en) * 1975-07-08 1979-11-27 Exxon Research & Engineering Co. Process for regenerating metal-contaminated hydrocarbon conversion catalysts
US4009121A (en) * 1975-08-26 1977-02-22 Exxon Research And Engineering Company Method of temperature control in catalyst regeneration
US4162213A (en) * 1976-04-29 1979-07-24 Mobil Oil Corporation Catalytic cracking of metal-contaminated oils
US4143521A (en) * 1977-02-08 1979-03-13 Stone & Webster Engineering Corporation Process for the production of ethylene
US4444651A (en) * 1979-11-14 1984-04-24 Ashland Oil, Inc. Carbo-metallic oil conversion with controlled CO:CO2 ratio in multistage regeneration
US4615795A (en) * 1984-10-09 1986-10-07 Stone & Webster Engineering Corporation Integrated heavy oil pyrolysis process
US4732740A (en) * 1984-10-09 1988-03-22 Stone & Webster Engineering Corporation Integrated heavy oil pyrolysis process
EP0344376A1 (en) * 1988-06-03 1989-12-06 Ching Piao Lin Process for converting heavy hydrocarbons to lighter hydrocarbons
US5087349A (en) * 1988-11-18 1992-02-11 Stone & Webster Engineering Corporation Process for selectively maximizing product production in fluidized catalytic cracking of hydrocarbons
US5120892A (en) * 1989-12-22 1992-06-09 Phillips Petroleum Company Method and apparatus for pyrolytically cracking hydrocarbons
WO1997034966A1 (en) * 1996-03-20 1997-09-25 Ormat Process Technologies, Inc. Solvent deasphalting unit and method for using the same
US6033555A (en) * 1997-06-10 2000-03-07 Exxon Chemical Patents Inc. Sequential catalytic and thermal cracking for enhanced ethylene yield
US6303842B1 (en) 1997-10-15 2001-10-16 Equistar Chemicals, Lp Method of producing olefins from petroleum residua
US6013852A (en) * 1997-11-21 2000-01-11 Shell Oil Company Producing light olefins from a contaminated liquid hydrocarbon stream by means of thermal cracking
MY119577A (en) * 1997-11-21 2005-06-30 Shell Int Research Producing light olefins from a contaminated liquid hydrocarbon stream by means of thermal cracking
US20060116543A1 (en) * 1999-07-07 2006-06-01 Naphtachimie S.A. & Bp Chemicals Limited Method and apparatus for steam cracking hydrocarbons
US7288690B2 (en) * 1999-07-07 2007-10-30 Bp Chemicals Limited Method and apparatus for steam cracking hydrocarbons
US20070029228A1 (en) * 2004-03-29 2007-02-08 Nippon Oil Corporation Hydrocracking catalyst and process for producing liquid hydrocarbon
US20080306321A1 (en) * 2004-03-29 2008-12-11 Nippon Oil Corporation Process for producing liquid hydrocarbon with hydrocracking catalyst
US7700818B2 (en) 2004-03-29 2010-04-20 Nippon Oil Corporation Process for producing liquid hydrocarbon with hydrocracking catalyst
US20100170828A1 (en) * 2006-03-30 2010-07-08 Nippon Oil Corporation Hydrocracking catalyst and process for producing fuel base material
US8288303B2 (en) 2006-03-30 2012-10-16 Nippon Oil Corporation Hydrocracking catalyst and process for producing fuel base material
US20070284285A1 (en) * 2006-06-09 2007-12-13 Terence Mitchell Stepanik Method of Upgrading a Heavy Oil Feedstock
US8658022B2 (en) 2010-11-23 2014-02-25 Equistar Chemicals, Lp Process for cracking heavy hydrocarbon feed
US8658019B2 (en) 2010-11-23 2014-02-25 Equistar Chemicals, Lp Process for cracking heavy hydrocarbon feed
US8663456B2 (en) 2010-11-23 2014-03-04 Equistar Chemicals, Lp Process for cracking heavy hydrocarbon feed
US9181146B2 (en) 2010-12-10 2015-11-10 Exxonmobil Chemical Patents Inc. Process for the production of xylenes and light olefins
US20120168348A1 (en) * 2010-12-29 2012-07-05 Coleman Steven T Process for cracking heavy hydrocarbon feed
US8658023B2 (en) * 2010-12-29 2014-02-25 Equistar Chemicals, Lp Process for cracking heavy hydrocarbon feed
US8921633B2 (en) 2012-05-07 2014-12-30 Exxonmobil Chemical Patents Inc. Process for the production of xylenes and light olefins
US8937205B2 (en) 2012-05-07 2015-01-20 Exxonmobil Chemical Patents Inc. Process for the production of xylenes
US9181147B2 (en) 2012-05-07 2015-11-10 Exxonmobil Chemical Patents Inc. Process for the production of xylenes and light olefins
US10898885B2 (en) 2016-04-11 2021-01-26 Saudi Arabian Oil Company Nano-sized zeolite supported catalysts and methods for their production
US10603657B2 (en) 2016-04-11 2020-03-31 Saudi Arabian Oil Company Nano-sized zeolite supported catalysts and methods for their production
US11084992B2 (en) 2016-06-02 2021-08-10 Saudi Arabian Oil Company Systems and methods for upgrading heavy oils
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US10689587B2 (en) 2017-04-26 2020-06-23 Saudi Arabian Oil Company Systems and processes for conversion of crude oil
US11001770B2 (en) 2017-07-17 2021-05-11 Saudi Arabian Oil Company Systems and methods for processing heavy oils by oil upgrading followed by refining
US10696910B2 (en) 2017-07-17 2020-06-30 Saudi Arabian Oil Company Systems and methods for processing heavy oils by oil upgrading followed by distillation
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US10689585B2 (en) 2017-07-17 2020-06-23 Saudi Arabian Oil Company Systems and methods for processing heavy oils
CN111116292A (zh) * 2018-10-30 2020-05-08 中国石油化工股份有限公司 石油烃制备低碳烯烃的方法及装置
CN115698232A (zh) * 2020-04-20 2023-02-03 埃克森美孚化学专利公司 含氮进料的烃热解

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SE7409669L (nl) 1975-01-31
SU650512A3 (ru) 1979-02-28
AU7122674A (en) 1976-01-15
AR214162A1 (es) 1979-05-15
GB1463392A (en) 1977-02-02
DK404774A (nl) 1975-04-07
DE2419436A1 (de) 1975-02-13
CA1013773A (en) 1977-07-12
SE391530B (sv) 1977-02-21
AT340554B (de) 1977-12-27
FR2239518B1 (nl) 1977-10-14
TR18059A (tr) 1976-09-10
FR2239518A1 (nl) 1975-02-28
NO742749L (nl) 1975-02-24
ES426794A1 (es) 1976-07-16
BR7404967A (pt) 1976-02-17
NL7405264A (nl) 1975-02-03
JPS5037704A (nl) 1975-04-08
IN144320B (nl) 1978-04-29
ATA620374A (de) 1977-04-15

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