EP0100401A1 - Zurückgewinnung von Lösungsmitteln in Kohlenwasserstoffbehandlungsanlagen - Google Patents

Zurückgewinnung von Lösungsmitteln in Kohlenwasserstoffbehandlungsanlagen Download PDF

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Publication number
EP0100401A1
EP0100401A1 EP83104308A EP83104308A EP0100401A1 EP 0100401 A1 EP0100401 A1 EP 0100401A1 EP 83104308 A EP83104308 A EP 83104308A EP 83104308 A EP83104308 A EP 83104308A EP 0100401 A1 EP0100401 A1 EP 0100401A1
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Prior art keywords
solvent
zone
extract
pressure
vaporization
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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.)
Withdrawn
Application number
EP83104308A
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English (en)
French (fr)
Inventor
Philip Barkley Sherman
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Texaco Development Corp
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Texaco Development Corp
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Filing date
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Priority claimed from US06/377,293 external-priority patent/US4390418A/en
Priority claimed from US06/377,294 external-priority patent/US4419227A/en
Application filed by Texaco Development Corp filed Critical Texaco Development Corp
Publication of EP0100401A1 publication Critical patent/EP0100401A1/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Withdrawn legal-status Critical Current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
    • C10G21/00—Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents
    • C10G21/28—Recovery of used solvent
    • 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
    • C10G21/00—Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents

Definitions

  • the invention relates to an improved process for the recovery of solvent employed in processing a petroleum oil fraction containing constituents having different physical and chemical properties.
  • the invention relates to a method for recovering solvent from hydrocarbon extract in a lubricating oil solvent refining process utilizing N-methyl-2-pyrrolidone as a solvent.
  • aromatic and unsaturated components of a hydrocarbon oil charge stock may be separated from the more saturated hydrocarbon components by various processes involving solvent extraction of the aromatic and unsaturated hydrocarbons.
  • Suitable solvents have an affinity for at least one component of the hydrocarbon oil charge stock and are partially immiscible with the charge stock under the temperature and pressure conditions employed in the solvent extraction step.
  • Two liquid phases are present in the extraction zone; the two liquid phases generally consist essentially of an extract phase containing the major amount of the solvent together with dissolved aromatic components cf the charge stock and a raffinate phase containing non-aromatic components of the charge stock together with a minor amount of solvent.
  • solvents which are known to be useful for solvent extraction processing of petroleum base lubricating oil stocks are furfural, N-methyl-2-pyrrolidone, phenols, and other various well known organic and inorganic solvents.
  • furfural N-methyl-2-pyrrolidone
  • phenols phenols
  • organic and inorganic solvents The removal of aromatics and other undesirable constituents from lubricating oil base stocks improves the viscosity index, color, oxidative stability, thermal stability, and inhibition response of the base oils and the lubricating oil products produced from hydrocarbon feedstocks.
  • N-methyl-2-pyrrolidone has displaced furfural and phenol in importance as a preferred solvent for extracting aromatic hydrocarbons from mixtures of aromatic and non-aromatic hydrocarbons.
  • Some of the advantages of N-methyl-2-pyrrolidone as solvent are referred to, for example, in U.S. Patent 4,057,491.
  • N-methyl-2-pyrrolidone is effective for the solvent extraction of aromatic components from lubricating oil charge stocks at relatively lower temperatures and lower solvent-to-oil dosages than most other known solvents.
  • N-methyl-2-pyrrolidone is generally the most preferred solvent because of its chemical stability, low toxicity and its ability to produce refined oils of improved quality.
  • the process of this invention is useful for upgrading existing N-methyl-2-pyrrolidone refining installations employing a single or multiple stage solvent recovery system and steam or inert gas stripping of the solvent from the products.
  • the process of this invention is also particularly suited to the conversion of furfural and phenol process installations to N-methyl-2-pyrrolidone solvent systems with substantial savings in the energy requirements of the solvent refining process.
  • N-methyl-2-pyrrolidone from oil-solvent mixtures, e.g., the extract phase and the raffinate phase of a solvent refining system wherein solvent is separated from oil-solvent mixtures by a combination of distillation and stripping
  • stripping with an inert gas rather than with steam for solvent purification often reduces the energy requirements of the process, as compared with conventional steam stripping.
  • Inert gas stripping has been disclosed, for example, in U.S. 2,923,680; 4,013,549 and 4,057,491.
  • the solvent extraction step is carried out under conditions effective to recover about 30 to 90 volume percent of the lubricating oil charge as raffinate or refined oil and to extract about 10 to 70 volume percent of the charge as an aromatic extract.
  • the lubricating oil stock is contacted with a solvent, e.g., N-methyl-2-pyrrolidone, at a temperature at least 5 C, preferably at least 50°C, below the temperature of complete miscibility of said lubricating oil stock in the solvent.
  • a solvent e.g., N-methyl-2-pyrrolidone
  • operating conditions are selected to produce a primary raffinate having a dewaxed viscosity index of about 75 to 100, and preferably about 85 to 96.
  • Solvent extraction temperatures within the range of 43 to 100°C (110 to 212 0 F), preferably within the range of 54 to 95°C (130 to 205°F), and solvent dosages within the range of 50 to 500 volume percent, basis hydrocarbon feedstock, and preferably within the range of 100 to 300 volume percent, are suitable.
  • Extraction pressure at the solvent to raffinate interface is preferably 1.4 bar to 2 bar. Water or wet solvent may be injected into the bottom of the extractor to control solvent power and selectivity.
  • the primary raffinate is dewaxed to the desired pour point.
  • the refined or dewaxed oil may be subjected to a finishing treatment for color and stability improvement, for example, mild hydrogenation.
  • the mechanical feasibility of the process depends on a significant density difference between the solvent-rich phase, or extract phase, and the oil-rich phase, or raffinate phase.
  • the density difference increases with increased solvent dosage.
  • the density difference can become so low as to severely limit the throughput of feed to the solvent extraction tower.
  • N-methyl-2-pyrrolidone is such an effective solvent for aromatics that in the case of some hydrocarbon charge stocks the solvent dosage needed to produce the desired raffinate quality is impractically low.
  • the minimum practical dosage i.e., about 100 percent
  • temperature i.e., about 60°C (140°F)
  • the refined oil quality is higher than desired and in some cases the refined oil yield is lower than desired.
  • the process of the invention overcomes this problem by operating the extraction step with a dry solvent dosage effective for rapid separation of the two liquid phases within the extraction tower, and refluxing the extraction tower by the introduction of water or wet solvent into the extraction tower near the point of withdrawal of the extract phase, i.e. between the point of introduction of the hydrocarbon feedstock to the separation system and the point of withdrawal of the extract phase, to obtain the desired quality raffinate product with a high yield of refined oil.
  • the present invention provides improvements in the methods of separating solvent from the extract and raffinate products, eliminating oil contamination in the solvent, and controlling the water content of the solvent in the solvent refining system, employing N-methyl-2-pyrrolidone as solvent.
  • the present invention provides a process in which dry solvent is used as the primary solvent in the extraction tower and water or wet solvent is employed as a reflux whereby a high yield of refined oil of desired quality at a given solvent dosage is obtained.
  • the solvent recovery may be simplified with a resultant savings in energy requirements of the process.
  • the present invention provides an improved method for recovery of solvent from the extract phase obtained on solvent refining lubricating oil base stocks wherein solvent is removed from the extract mixture by vaporization of solvent partially in a first low pressure solvent vaporization zone and then vaporizing further portions of the solvent from the extract in a plurality of zones at progressively higher pressures with heat from an external source supplied only to the last high pressure vaporization zone and heat for each preceding vaporization zone supplied by heat exchange with vapors from each succeeding vaporization zone and mixing part of the vapors from the last high pressure vaporization zone with vapors from a medium pressure vaporization zone as heat supply to the lower pressure solvent vaporization zone.
  • additional solvent is recovered from the extract by vaporization in a subatmospheric pressure flash zone following the high pressure vaporization zone at a temperature at least 5°C higher than the temperature of the high pressure zone.
  • solvent remaining in the extract fraction from the high pressure vaporization zone is substantially completely recovered from the extract by flash vaporization of solvent from the extract fraction in a subatmospheric pressure flash zone following the high pressure vaporization zone, and then by vaporization of further amounts of solvent from the extract in a heater in the presence of an inert gas and at a temperature at least 5 0 C higher than the temperature in the high pressure flash vaporization zone followed by stripping of the extract with an inert gas at a low superatmospheric pressure.
  • petroleum base lubricating oil feedstock is supplied to the solvent refining process through line 1 and split into two streams.
  • Part of the feedstock passes through line 2, heater 3 and line 4 to the upper part of absorber tower 5 wherein the lubricating oil feedstock is brought into intimate countercurrent contact with an inert stripping gas, e.g. nitrogen, containing solvent vapors entering the lower part of the absorber tower 5 through line 6.
  • Absorber tower 5 comprises a countercurrent vapor-liquid contacting tower wherein liquid flowing down the tower is intimately contacted with gases and vapors passing upwardly through the tower.
  • Means for ensuring intimate contact between vapor and liquid e.g. bubble cap trays, perforated plates, packing material, or the like, are provided within the tower.
  • a preferred embodiment of the process is illustrated and described as a specific example; in this example, the lubricating oil feedstock from line 2 is heated in heater 3 to a temperature of 66°C and absorber 5 is operated at 1.7 bar. In the absorber 5, solvent vapors are absorbed by the lubricating oil feedstock and the recovered solvent returned with the feedstock to the process. Stripping medium, from which solvent has been removed, is discharged through line 7 and heater 8 for reuse in the process.
  • a second portion of the lubricating oil feedstock from line 1 is passed through line 12, heater 13 and line 14 into the upper part of an absorber tower 15 wherein the lubricating oil feedstock is brought into intimate countercurrent contact with a mixture of steam and solvent vapors entering the lower part of absorber 15 through line 16.
  • Absorber 15 comprises a countercurrent contacting tower similar to absorber 5 described above and, as a specific example, may be operated at a pressure of 1.1 bar and a temperature of 102 to 104°C. Steam from which solvent has been removed is discharged through line 17 to condenser 18 wherein the steam is condensed and the condensate accumulated in "rate" drums 19 where it is stored until tested for solvent content and, if sufficiently low, released to the sewer system.
  • the lubricating oil feedstock streams discharged from the lower part of absorbers 5 and 15 are combined and passed through line 22, heater 23, and line 24 to the lower part of extraction tower 25 wherein the lubricating oil feedstock is intimately countercurrently contacted with dry N-methyl-2-pyrrolidone solvent introduced into the upper part of extraction tower 25 through line 26.
  • dry N-methyl-2-pyrrolidone means N-methyl-2-pyrrolidone containing 0.3 weight percent water or less.
  • extract tower 25 is operated at an interface pressure of 1.4 to 2 bar; in this example 1.4 bar with a raffinate outlet temperature of 63 0 C and an extract outlet temperature of 46 C.
  • the raffinate mixture comprising typically 85 percent hydrocarbon oil admixed with solvent is discharged from the extraction tower 25 through line 28 and processed for the recovery of raffinate from the solvent.
  • the raffinate after separation of solvent, is a solvent refined lubricating oil base stock, the desired product of the process. The recovery of solvent from the raffinate is described hereinafter.
  • Flash tower 35 is provided with vapor-liquid contacting means, e.g. cascade trays, in its upper part to effect countercurrent contact between reflux liquid flowing down the tower and solvent vapors flowing up the tower. A part of the extract mixture from the bottom of tower 35 is cooled by .means not illustrated and is reintroduced through line 37 into the upper part of tower 35 as reflux in known manner. Flash tower 35 may be operated at a pressure in the range of 1.15 to 1.4 bar; in this specific example, the flash tower pressure is 1.15 bar and the flash tower temperature is about 20 2 o C.
  • Solvent vapors separated from the extract mixture in flash tower 35 contain water vapors.
  • the solvent vapors mixed with water vapor pass through line 39 to heat exchanger 33 where most of the solvent vapor and a little of the water vapor are condensed preheating the extract mixture from line 31.
  • Condensate and uncondensed vapors pass through line 41 to accumulator 42 as part of the feed to drying tower 45 as described hereinafter.
  • the medium pressure flash tower 48 suitably is operated at a pressure in the range of 1.7 to 1.97 bar; in this specific example, the medium flash tower pressure is 1.72 bar and the flash tower temperature is 232°C.
  • a minor portion of the extract solvent mixture from the bottom of flash tower 35 is introduced to the upper part of the flash tower 48 as reflux in known manner, not illustrated.
  • the solvent vapors leaving the top of medium pressure flash tower 48 through line 49 are passed to heat exchanger-condenser 34 in indirect heat exchange with the extract mixture from the bottom of extraction tower 25, condensing part of the solvent vapors and preheating the extract mixture prior to its introduction to low pressure flash tower 35.
  • Condensate from heat exchanger-condenser 34 is passed through line 50 as dry solvent for reuse as described hereinafter.
  • Uncondensed solvent and water vapors from heat exchanger 34 pass through line 51 to drying tower 45 as part of the feed to the drying tower described hereinafter.
  • Extract mixture from which a further part of the solvent has been removed by vaporization in flash tower 48 is withdrawn from the lower part of flash tower 48 and passed through heat exchanger 52 and line 53 to heater 54 where the mixture is heated to a temperature in the range of 288 to 310°C and introduced into high pressure flash tower 55 for the removal of most of the remaining solvent from the extract mixture.
  • the high pressure flash tower 55 suitably is operated at a pressure within the range of 2.9 to 3.14 bar and in this specific example at 2.9 bar.
  • a minor portion of the extract solvent mixture from the bottom of flash tower 35 is introduced to the upper part of the high pressure flash tower 55 as reflux in known manner, not illustrated.
  • a portion of the solvent vapors from high pressure flash tower 55 is passed through line 57 to line 49 into admixture with solvent vapors from medium pressure flash tower 48 and the mixture passed through line 49 to heat exchanger 34 to supply additional heat to the extract mixture from extraction tower 25 and maintain the desired temperature in low pressure flash tower 35.
  • solvent vapors from the high pressure flash tower 55 are passed through line 57 to line 49 and heat exchanger 34 for this purpose.
  • the hydrocarbon oil extract withdrawn from the bottom of high pressure flash tower 55 through expansion valve 58 and line 59 still contains some solvent, for example, 20 volume percent solvent and 80 volume percent hydrocarbon extract.
  • This extract mixture is reheated in heater 60 to a temperature above the temperature of high pressure flash tower 55 and introduced into vacuum flash tower 65 for further recovery of solvent from the extract.
  • the vacuum flash tower may operate at a pressure within the range of 0.25 to 0.55 bar, and at a temperature in the range of 293 to 315°C; in this specific example the vacuum flash tower pressure is 0.45 bar and the operating temperature is 293°C.
  • a portion of the extract solvent mixture from the bottom of flash tower 35 is supplied to the top of vacuum flash tower 65 as reflux in known manner, not illustrated.
  • Extract stripping tower 71 is typically a countercurrent vapor-liquid contact column provided with bubble cap trays in which the liquid extract flowing downwardly through the column is contacted with inert stripping gas introduced into the lower portion of tower 71 through line 72. A part of the extract mixture from the bottom of stripping tower 71 is cooled and returned to the upper portion of the tower as reflux through line 73.
  • Inert stripping gas e.g. nitrogen
  • stripped solvent vapors are discharged from the upper part of stripping tower 71 through line 76 to condenser 77 where solvent vapors are condensed.
  • Solvent condensate is collected in condensate accumulator 78 and returned through line 79 to dry solvent storage 92 for recycle to extraction tower 25.
  • Inert gas separated from the condensate solvent in separator 78 is recirculated by compressor 80 to line 6 and absorber 5 for the recovery of trace amounts of solvent contained in the recirculated stripping gas.
  • extract stripping tower 71 is operated at a pressure just above atmospheric pressure, e.g., 1.1 bar to 1.3 bar and a temperature of 299°C.
  • Condenser 77 cools the stripping gas and solvent to a temperature of the order of 60°C effecting condensation of the major part of the solvent from the nitrogen or other stripping gas prior to recycle to absorber 5.
  • Absorber 5 recovers substantially all of the residual solvent from the recycle nitrogen stream.
  • Raffinate mixture taken overhead from extraction tower 25 through line 28 typically comprises about 15 volume percent solvent and 85 volume percent hydrocarbons.
  • the extraction tower is operated with a dry solvent dosage of 100 volume percent, i.e. one volume of solvent from each volume of oil charge stock.
  • raffinate mixture is discharged from the -extraction tower at a temperature of 63°C.
  • the raffinate mixture from line 28 is collected in run tank 82, and heated in heat exchanger 83 and in a fired heater 85 prior to introduction into vacuum flash tower 86 wherein solvent is separated from the raffinate mixture.
  • raffinate vacuum flash tower 86 is operated at a pressure of 0.7 bar and a temperature of the order of 298°C. Reflux from a suitable source, e.g. dry N-methyl-2-pyrrolidone,is supplied to the top of vacuum flash tower 86 through line 87 as reflux.
  • raffinate flash tower 86 separation of the major portion of the solvent from the raffinate takes place.
  • Solvent vapors are withdrawn from the top of flash tower 86 through line 88, heat exchanger 83, and cooler 89 to solvent accumulator 90.
  • Condensate solvent from accumulators 90 and 68 flow through line 79 to run tank 92 from which dry solvent is withdrawn through line 26 to extraction tower 25.
  • Uncondensed gases are withdrawn from solvent accumulator 90 through line 93 to a suitable vacuum source, not illustrated, and may be discarded or further processed for the recovery of solvent vapors therefrom.
  • Raffinate still containing some solvent, is withdrawn from the lower part of vacuum flash tower 86 through line 95 to the upper part of stripping tower 96, wherein residual solvent is removed from the raffinate by stripping with inert gas.
  • Inert gas from absorber 5 is introduced into the lower part of stripping tower 96 via lines 7 and 97.
  • a minor portion of the raffinate from the raffinate cooler 98 is reintroduced to the upper part of the raffinate stripping tower 96 as reflux in known manner, not illustrated.
  • raffinate stripping tower 96 is operated at a pressure just above atmospheric pressure, e.g. 1.1 to 1.3 bar and at a temperature of 288°C.
  • Nitrogen containing solvent from stripper 96 is combined with nitrogen containing solvent from stripper 71 and cooled in condenser 77 for condensation of solvent from the stripping gas recirculated to absorber 3.
  • Raffinate substantially free from solvent, is withdrawn as a product of the process from the lower portion of stripper 96 through heat exchanger 98 where it is cooled and discharged to line 100 as the refined lubricating oil stock, the principal product of the process.
  • the solvent purification system of this process comprises drying tower 45 where water vapor or steam mixed with solvent vapors from low pressure flash tower 35 and from medium pressure flash tower 48 are processed for the recovery of dry solvent for reuse in extraction tower 25.
  • Solvent vapors containing water vapor or steam are passed from low pressure flash tower 35 through line 39 to heat exchanger 33 wherein the vapors are cooled and partially condensed by heat exchange with the extract mixture leaving the bottom of extraction tower 25 through line 31.
  • the resulting vapor-liquid mixture comprising wet solvent, solvent vapors, and water vapor pass through line 41 to accumulator drum 42 wherein wet solvent (liquid) is separated from solvent vapors and steam.
  • wet solvent is introduced into drying tower 45 through line 101 and steam containing solvent vapors is introduced into drying tower 45 through line 102 wherein dry solvent is separated from steam and solvent vapors.
  • Solvent vapors from medium pressure separator 48 containing water vapor are passed through line 49 to heat exchanger-condenser 34 wherein they are cooled and partially condensed by indirect heat exchange with extract mixture from line 31.
  • heat exchanger-condenser 34 the extract mixture is preheated prior to its introduction to low pressure flash tower 35 condensing a portion of the solvent vapors from line 49.
  • the condensed solvent is essentially free from water vapor and is withdrawn from heat exchanger-condenser 34 through line 50 to line 49B and passed through line 106 to dry solvent accumulator 92. Uncondensed vapor from heat exchanger-condenser 34 is passed through line 51 to drying tower 45 for the recovery of solvent therefrom.
  • Drying tower 45 comprises a fractionating column provided with suitable means, for example, perforated plates or bubble cap trays, for ensuring intimate countercurrent contact between vapors rising upwardly through the column and liquid flowing downwardly therethrough. Drying tower 45 is provided with a reboiler 103 at the bottom of the fractionating column to vaporize all of the water and part of the solvent entering the drying tower with the various feed streams. Dry N-methyl-2-pyrrolidone is withdrawn from the bottom of drying tower 45 through line 104, cooled in heat exchanger 105, and passed through line 106 to dry solvent accumulator 92 as dry solvent for extraction tower 25. In this specific example, drying tower 45 is operated at a pressure of 1.08 bar with a bottom temperature, i.e. reboiler temperature, of 216°C and a tower top temperature of 104°C to 132°C.
  • suitable means for example, perforated plates or bubble cap trays
  • the hydrocarbon oil extract withdrawn from the bottom of high pressure flash tower 55 through expansion valve 58 and line 59 still contains some solvent, for example, 20 volume percent solvent and 80 volume percent hydrocarbon extract.
  • This extract mixture is introduced into vacuum flash tower 160 for further recovery of solvent from the extract.
  • the vacuum flash tower may operate at a pressure within the range of 0.25 to 0.55 bar, and at a temperature in the range of 235 0 C to 260°C; in this specific example the vacuum flash tower pressure is 0.45 bar and the operating temperature is 243°C.
  • a minor portion of the extract solvent mixture from the bottom of flash tower 35 is supplied to the top of vacuum flash tower 160 as reflux in known manner, not illustrated.
  • the hydrocarbon oil extract withdrawn from the bottom of the vacuum flash tower 160 still contains some solvent, for example, 7 volume percent solvent and 93 volume percent hydrocarbon extract.
  • This extract mixture is reheated in the presence of inert gas in heater 165 to a temperature at least 5°C higher than the temperature of the high pressure flash tower 55, e.g., in the range of 293 to 315 0 C, and introduced into the upper portion of the extract stripping tower 71.
  • an inert gas e.g. nitrogen
  • an inert gas is introduced into the heater coil of heater 165 through lines 6 and 64 from the compressor 80 to increase the solvent vaporization within heater 165.
  • an inert gas e.g. nitrogen
  • an inert gas is introduced into the heater coil of heater 165 through lines 6 and 64 from the compressor 80 to increase the solvent vaporization within heater 165.
  • an inert gas e.g. nitrogen

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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)
  • Pyrrole Compounds (AREA)
  • Vaporization, Distillation, Condensation, Sublimation, And Cold Traps (AREA)
  • Extraction Or Liquid Replacement (AREA)
  • Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
EP83104308A 1982-05-12 1983-05-02 Zurückgewinnung von Lösungsmitteln in Kohlenwasserstoffbehandlungsanlagen Withdrawn EP0100401A1 (de)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US06/377,293 US4390418A (en) 1982-05-12 1982-05-12 Recovery of solvent in hydrocarbon processing systems
US377293 1982-05-12
US06/377,294 US4419227A (en) 1982-05-12 1982-05-12 Recovery of solvent from a hydrocarbon extract
US377294 1982-05-12

Publications (1)

Publication Number Publication Date
EP0100401A1 true EP0100401A1 (de) 1984-02-15

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EP83104308A Withdrawn EP0100401A1 (de) 1982-05-12 1983-05-02 Zurückgewinnung von Lösungsmitteln in Kohlenwasserstoffbehandlungsanlagen

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EP (1) EP0100401A1 (de)
KR (1) KR850001273B1 (de)
AU (1) AU554865B2 (de)
ES (1) ES8407086A1 (de)
MX (1) MX166951B (de)

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
RU2651547C1 (ru) * 2017-06-05 2018-04-20 Общество с ограниченной ответственностью "ВОКСТЭК" Способ регенерации растворителя в процессах депарафинизации и обезмасливания
CN113617052A (zh) * 2021-07-19 2021-11-09 茂名海和石油化工有限公司 一种以氮气为气源的吹脱法炼油工艺

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3461066A (en) * 1966-12-23 1969-08-12 Texaco Inc Solvent recovery in the solvent extraction of hydrocarbon oils
US4057491A (en) * 1976-03-26 1977-11-08 Exxon Research & Engineering Co. Solvent recovery process for N-methyl-2-pyrrolidone in hydrocarbon extraction
GB2020559A (en) * 1978-05-10 1979-11-21 Lummus Co Solvent recovery process for processing of hydrocarbons
DE3002984A1 (de) * 1980-01-29 1981-08-06 Edeleanu Gmbh, 6000 Frankfurt Verfahren zur rueckgewinnung von loesungsmitteln aus loesungsmittelhaltigen kohlenwasserstoffphasen in kohlenwasserstoff-raffinationssystemen

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3461066A (en) * 1966-12-23 1969-08-12 Texaco Inc Solvent recovery in the solvent extraction of hydrocarbon oils
US4057491A (en) * 1976-03-26 1977-11-08 Exxon Research & Engineering Co. Solvent recovery process for N-methyl-2-pyrrolidone in hydrocarbon extraction
GB2020559A (en) * 1978-05-10 1979-11-21 Lummus Co Solvent recovery process for processing of hydrocarbons
DE3002984A1 (de) * 1980-01-29 1981-08-06 Edeleanu Gmbh, 6000 Frankfurt Verfahren zur rueckgewinnung von loesungsmitteln aus loesungsmittelhaltigen kohlenwasserstoffphasen in kohlenwasserstoff-raffinationssystemen

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
RU2651547C1 (ru) * 2017-06-05 2018-04-20 Общество с ограниченной ответственностью "ВОКСТЭК" Способ регенерации растворителя в процессах депарафинизации и обезмасливания
CN113617052A (zh) * 2021-07-19 2021-11-09 茂名海和石油化工有限公司 一种以氮气为气源的吹脱法炼油工艺

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MX166951B (es) 1993-02-15
KR850001273B1 (ko) 1985-09-04
ES522342A0 (es) 1984-08-16
ES8407086A1 (es) 1984-08-16
AU1421183A (en) 1983-11-17
KR840004779A (ko) 1984-10-24
AU554865B2 (en) 1986-09-04

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