EP0373983A1 - Verfahren zur gleichzeitigen Ausscheidung von CO2 und Bearin aus Methan, C2 und höheren Kohlenwasserstoffen und CO2 enthatenden gasförmigen Kohlenwasserstoffen - Google Patents

Verfahren zur gleichzeitigen Ausscheidung von CO2 und Bearin aus Methan, C2 und höheren Kohlenwasserstoffen und CO2 enthatenden gasförmigen Kohlenwasserstoffen Download PDF

Info

Publication number
EP0373983A1
EP0373983A1 EP89403123A EP89403123A EP0373983A1 EP 0373983 A1 EP0373983 A1 EP 0373983A1 EP 89403123 A EP89403123 A EP 89403123A EP 89403123 A EP89403123 A EP 89403123A EP 0373983 A1 EP0373983 A1 EP 0373983A1
Authority
EP
European Patent Office
Prior art keywords
solvent
rich
hydrocarbons
gas
methane
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Granted
Application number
EP89403123A
Other languages
English (en)
French (fr)
Other versions
EP0373983B1 (de
Inventor
Claude Blanc
Henri Paradowski
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.)
Elf Exploration Production SAS
Original Assignee
Societe National Elf Aquitaine
Societe Nationale Elf Aquitaine Production SA
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Application filed by Societe National Elf Aquitaine, Societe Nationale Elf Aquitaine Production SA filed Critical Societe National Elf Aquitaine
Priority to EP93107550A priority Critical patent/EP0556875B1/de
Priority to AT89403123T priority patent/ATE100852T1/de
Publication of EP0373983A1 publication Critical patent/EP0373983A1/de
Application granted granted Critical
Publication of EP0373983B1 publication Critical patent/EP0373983B1/de
Priority to GR950402736T priority patent/GR3017623T3/el
Anticipated expiration legal-status Critical
Expired - Lifetime legal-status Critical Current

Links

Images

Classifications

    • 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
    • C10G5/00—Recovery of liquid hydrocarbon mixtures from gases, e.g. natural gas
    • C10G5/04—Recovery of liquid hydrocarbon mixtures from gases, e.g. natural gas with liquid absorbents
    • 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
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1025—Natural gas

Definitions

  • the invention relates to a process for simultaneous decarbonation and degassing of a gaseous mixture consisting mainly of hydrocarbons consisting of methane and C2 and higher hydrocarbons and also containing CO2 and optionally one or more non-sulfurized compounds with low boiling point such as H2, CO, N2 and argon.
  • the method according to the invention makes it possible to directly separate a gas mixture of the aforementioned type into three components, namely: - a treated gas consisting mainly of methane and C2 hydrocarbons and whose CO2 molar content is at most equal to 2%, a section of hydrocarbons containing at least 80 mol% of C3 hydrocarbons and more present in the gas mixture to be treated, and - a stream of acid gas consisting of CO2 containing less than 10 mol% of hydrocarbons, expressed in methane equivalent, relative to CO2.
  • decarbonation and degassing operations are generally carried out separately and are part of a succession of operations carried out on the gas mixture to be treated and mainly comprising an elimination of the acid gas CO2, drying, adsorption of the water on a suitable solid such as a molecular sieve, a separation by cryogenic distillation between -30 ° C and -90 ° C associated or not with a solvent extraction in order to obtain the cut of natural gas liquid, and finally reheating the treated gas to ambient temperature in order to generally supply the commercial gas network.
  • the dehydrated and refrigerated natural gas is separated, in a first column (demethanizer) at the head of which is injected an additive consisting of a liquid fraction of C4 hydrocarbons and more, into a gas phase containing methane and lighter compounds and a liquid fraction containing C2 and higher hydrocarbons and CO2.
  • This liquid fraction is separated, in a second column (de-ethanizer) into which a certain amount of the additive is also introduced, into a top fraction consisting of CO2 and a bottom fraction containing the C en hydrocarbons and more.
  • Said tail fraction is then separated, in a third column, into an overhead fraction consisting of a liquid cut of C2 to C4 hydrocarbons and into a tail fraction consisting of a liquid cut of C4 and higher hydrocarbons, which contains the major part of the butanes and higher hydrocarbons present in the treated natural gas and from which the appropriate quantity is taken to constitute the additive injected in the first and second columns.
  • This additive avoids the crystallization of CO2 at the top of the demethanizer and ensures the rupture of the azeotrope which forms between ethane and CO2 and facilitates the separation of these compounds in the de-ethanizer.
  • the aforementioned process is therefore essentially based on serial distillation operations.
  • the invention provides a process for simultaneous decarbonation and degassing of gas mixtures, which are available under an absolute pressure greater than 0.5 MPa and consist mainly of hydrocarbons consisting of methane and C2 and higher hydrocarbons and also contain CO2 and optionally one or more low-boiling non-sulfur compounds such as H2, CO, N2 and argon, such gas mixtures being, for example, of the natural gas type, said process making it possible to achieve more easily and at lower cost, in comparison with known processes, the objective of separating the gaseous mixture into the three components, namely treated gas consisting mainly of methane, liquid fraction of hydrocarbons in majority of hydrocarbons in C3 and above and containing, as necessary, a more or less large quantity of ethane and current of CO2, which have the specifications defined above.
  • the process according to the invention is of the type of process which is described in the US-A-3770622 quotation and in which the gas mixture is brought into contact, in a washing zone, with a solvent consisting of a liquid which dissolves CO2 and hydrocarbons in C2 and above and which has on the one hand, at atmospheric pressure, a boiling temperature greater than 40 ° C and on the other hand, at - 30 ° C, a viscosity less than 0.1 Pa.
  • methane equivalent is meant according to the invention as many pseudo-molecules with a single carbon atom as there are carbon atoms in the considered hydrocarbon molecule.
  • the solvent which is generally defined above for bringing it into contact with the gaseous mixture to be treated for the purpose of absorbing CO2 and C en and higher hydrocarbons, preferably has a viscosity of less than 0.05 Pa.s.
  • the solvent according to the invention may consist in particular of one or more liquid absorbents which are selective for CO2 and used in anhydrous form or as a mixture with water, the said solvent (s) being chosen from the amides of formulas aldehydes of formula formula esters Ccan to C4 alkanols, diethers of formula CH3-O ⁇ C2H4O ⁇ CH3, diether alcohols of formula R9O- C2H4- O - C2H4 - OH, lactones of formula and carbonate of propylene, with in these formulas R1 and R2, identical or different, denoting a hydrogen atom or an alkyl radical in C1 or C2, R3 being an alkyl radical in C3 or C4, R6 being an alkyl radical in C2 to C4 or a radical ⁇ C2H4O ⁇ R8 with R8 denoting a C1 or C2 alkyl radical and n being equal to 1 or 2, R7 being a Coy or C2 alkyl radical or a
  • Nonlimiting examples of liquid organic absorbents corresponding to the above formulas are such as N, N-dimethylformamide, N, N-dimethylacetamide, dimethoxymethane, diethoxymethane, dimethoxy-1,1 ethane, methanol, ethanol, ethylene dimethyl ether glycol, diethylene glycol dimethyl ether, ethylene glycol monomethyl ether, butyrolactone, propiolactone and propylene carbonate.
  • the contacting temperature of the gas mixture to be treated with the solvent in the washing zone is preferably between 0 ° C and -45 ° C.
  • the washing zone advantageously consists of one or more washing columns containing the appropriate number of theoretical washing stages, said columns being, for example, of the type of tray columns or even packed columns.
  • the temperature in each of the washing columns is kept substantially constant by indirect heat exchange, carried out at one or more points of the column in question, between the fluid medium contained in this column and a refrigerating fluid.
  • the demethanization treatment applied to the rich solvent is carried out, in particular, in two stages, namely a first stage in which the said rich solvent is subjected to a first expansion at an intermediate pressure capable of releasing a large fraction of the methane dissolved in said solvent to be demethanized and to produce a first gas rich in methane and a predemethanized fluid and a second step in which the predemethanized fluid is subjected to a second expansion then to a distillation so as to produce a second gas rich in methane and the demethanized rich solvent, the second methane-rich gas being compressed to the pressure of the first methane-rich gas and then mixed with the latter to form the methane-rich gas phase.
  • the methane-rich gas phase resulting from the demethization treatment applied to the rich solvent, is advantageously compressed to the pressure of the gas mixture to be treated, then it is cooled and mixed with the gas mixture to be treated before the latter is brought into contact. with the solvent in the washing area.
  • the treatment of the gaseous mixture containing CO2 and C hydrocar and higher hydrocarbons which is produced during the regeneration step of said treatment a), consists of washing said gaseous mixture by bringing this gaseous mixture into contact with a C5 and higher hydrocarbon solvent in a washing space operating at low temperature so as to produce the stream of acid gas rich in CO2 and a rich hydrocarbon solvent containing almost all of the C2 and higher hydrocarbons contained in said gaseous mixture and practically free of CO2, said washing being followed by regeneration of the rich hydrocarbon solvent to produce the cut of C2 and higher hydrocarbons and a regenerated hydrocarbon solvent which is recycles to the washing space.
  • the regeneration of the demethanized rich solvent, carried out during treatment a), is carried out by reheating said solvent to a temperature close to ambient, by dividing the reheated solvent into first and second streams, by directing the first stream directly to a regeneration area, directing the second stream to said regeneration area after having heated it by indirect heat exchange with the regenerated solvent, and subjecting the solvent to distillation in the regeneration area.
  • Said distillation can be carried out in the presence of a stream of inert gas, for example nitrogen, injected into the regeneration zone.
  • the temperature, below the temperature prevailing in the washing zone, to which said demethanized rich solvent is cooled to achieve its demixing is more particularly between -25 °. C and -80 ° C.
  • the regeneration of the purified solvent produced in one or other of the treatments b) and c), which leads to the production of the stream of acid gas rich in CO2 and having, expressed in methane equivalent, a hydrocarbon content of less than 10 % molar relative to CO2, can be carried out by any treatment making it possible to release the gaseous compounds dissolved in a liquid.
  • the regeneration of the purified solvent can be carried out by expansion of said purified solvent to a pressure greater than 100 kPa and for example between 150 kPa and 300 kPa and by stripping using an inert gas such as nitrogen. possibly associated with a heating of the purified solvent in the regeneration zone.
  • the regeneration of the purified solvent can also be carried out by heating the said purified solvent to a temperature close to ambient, by dividing the heated solvent into first and second streams, directing the first stream directly to a regeneration zone, by directing the second stream to this regeneration zone after having heated it by indirect heat exchange with the regenerated purified solvent, and by subjecting the solvent to distillation in the regeneration zone in order to produce the regenerated solvent and the regeneration current.
  • acid gas rich in CO2 supplied by the process by dividing the heated solvent into first and second streams, directing the first stream directly to a regeneration zone, by directing the second stream to this regeneration zone after having heated it by indirect heat exchange with the regenerated purified solvent, and by subjecting the solvent to distillation in the regeneration zone in order to produce the regenerated solvent and the regeneration current.
  • the gaseous mixture to be treated contains water and / or C5 and higher hydrocarbons
  • a pretreatment intended to remove all or part of these compounds before being brought into contact with the solvent in the zone of washing.
  • This pretreatment can consist of a distillation possibly carried out in the presence of solvent, taken from the solvent injected into the washing zone, to produce the pretreated gas mixture having a C6 hydrocarbon content and more than 0.1% by weight, a fraction of so-called heavy hydrocarbons containing almost all of the C6 and more hydrocarbons and all or part of the C5 hydrocarbons and, optionally, a liquid consisting of a mixture of solvent and water.
  • Said distillation of the gas mixture is carried out at a temperature at least equal to the temperature prevailing in the washing zone.
  • the gas mixture to be treated arriving via line 1 is introduced into the lower part of a distillation column 2, in which said gas mixture is optionally distilled in the presence of solvent removed, through line 41 emerging in the upper part of column 2, on the regenerated solvent 38 brought to the washing column 5, before passage of said solvent in a refrigeration zone 39 mounted on the conduit 6 for injecting the regenerated solvent in said washing column 5 , so as to produce on the one hand a dried gaseous mixture, evacuated from column 2 by a line 3 and whose hydrocarbon content in C6 and more is less than 0.1% by weight, and on the other hand a cut hydrocarbon containing almost all of the C6 hydrocarbons and more and possibly all or part of the C5 hydrocarbons, drawn off from column 2 by a pipe 4 and optionally a liquid drawn off column 2 through a conduit 54 and consisting of a mixture of solvent and water.
  • the dried gaseous mixture leaving column 2 through line 3 is introduced into the lower part of a washing column 5, for example of the plate column type, in which it is brought into contact, against the current, with regenerated cold solvent injected into the upper part of the column 5 via the line 6, after passing through the coolant 39, this contacting being carried out at a temperature of, for example, between 0 ° C. and -45 ° C., said temperature being controlled by passage of the liquid medium contained in column 5 in refrigerants 7.
  • a treated gas consisting mainly of methane and depleted in CO2 is removed, said treated gas being heated in a heating system 9 then directed, via a conduit 10, to a zone of use, while at the bottom of said column 5 is drawn off, via a conduit 11, a liquid phase consisting of the solvent enriched in CO2 and other compounds absorbed and called rich solvent.
  • the dried gas mixture is brought into contact with the solvent in the washing column 5 at an appropriate temperature in the range 0 ° C. to -45 ° C. and with a ratio of the flow rates of the gas mixture to be treated and of solvent such that on the one hand the treated gas collected, through line 8, at the head of column 5 has a molar CO2 content of at most equal to 2% and that on the other hand the rich solvent, flowing through line 11 , contains at least 80 mol% of C3 and higher hydrocarbons present in the dried gas mixture introduced in column 5.
  • the rich solvent circulating in the conduit 11 is introduced, after passage through the expansion valve 12, into the upper part of an expansion tank 13 in which a first methane-rich gas separates, which is removed at the head of the flask 13 by a conduit 14, and a predemethanized rich solvent, which is withdrawn from the bottom of the flask 13 by a conduit 15.
  • Said predemethanized rich solvent is subjected to a second expansion through an expansion valve 16 followed by a distillation in a distillation column 17 provided with a reboiler 18, so as to produce a second gas rich in methane, which is evacuated at the top of the column 17 by a conduit 19, and a liquid phase depleted in methane, called demethanized rich solvent, which is drawn off at the bottom of the column 17 by a pipe 27.
  • the second methane-rich gas circulating in the pipe 19 is caused to pass into a compressor 20 from which it leaves, via a pipe 21, to a pressure substantially equal to that of the first methane-rich gas passing through line 14, then these two methane-rich gases are mixed in line 22 and the gas phase resulting from this mixture is recycled, by means of a compressor 23 whose the outlet is extended by a line 24, a cooler 25 and a line 26, in the line 3 for supplying the dried gas mixture to the washing column 5.
  • the regeneration can be carried out in the presence of a stream of inert gas, in particular a stream of nitrogen, injected into the lower part of the column 33 through a conduit 43.
  • Said regeneration produces, on the one hand, a regenerated solvent drawn off at the bottom of the column 33, through a pipe 34, and used in the heat exchanger 35, to heat the second stream 31 of solvent rich in methanis to be regenerated, before being recycled, by the pump 37 and the pipe 38, to the washing column 5, and on the other hand a gaseous mixture discharged at the top of the column 33, by a pipe 42, and containing the CO2 as well as C2 and more hydrocarbons present in the demethanized rich solvent.
  • the gaseous mixture passing through the conduit 42 is washed against the current, in a washing tower 47 provided with a condenser 46 at the head and a reboiler 70 at the bottom and operating at low temperature, using a hydrocarbon solvent in C5 and no longer brought to the washing tower 47 via a pipe 53, said washing producing, on the one hand, a stream 44 of acid gas rich in CO2, which contains almost all of the CO2 present in the rich solvent demethanized and has, expressed in methane equivalent, a hydrocarbon content of less than 10 mol% relative to CO2, and, on the other hand, a rich hydrocarbon solvent 45 practically free of CO2 and containing almost all of the hydrocarbons C2 and more present in the gas mixture arriving via line 42.
  • the rich hydrocarbon solvent 45 is brought to a regeneration column 49 in which said solvent 45 is subjected to distillation to produce, on the one hand, a fraction of hydrocarbons 48 constituting the cut of C2 hydrocarbons and more containing at least 80 mol% of the C3 hydrocarbons and more contained in the gas to be treated brought to the washing column 5 by the line 3, and, on the other hand, a regenerated hydrocarbon solvent 50, which is recycled, by the pump 51, to the regeneration column 47 after refrigeration in the system 52 and passage in the conduit 53.
  • the embodiment of the method according to the invention differs from the embodiment illustrated in FIG. 1 only by the treatment of the demethanized rich solvent available at the outlet of the expansion valve 29 mounted on the line 27 through which the demethanized rich solvent is withdrawn from the demethanization column 17.
  • the operations carried out in column 2, as well as the operations for bringing the gas to be treated into contact with the solvent in column 5 for washing and demethanization of the rich solvent are therefore identical to those described with reference to FIG. 1.
  • the demethanized rich solvent, expanded by passage through the expansion valve 29, is refrigerated in the refrigerating system 40 with the result of the demixing of said solvent into two liquid phases, namely an upper hydrocarbon phase and a lower phase consisting of the solvent containing the majority CO2 and a certain amount of hydrocarbons.
  • the assembly is introduced into an extraction tower 56, in which it is brought into contact, against the current, with a refrigerated hydrocarbon solvent injected, through a conduit 57, into the lower part of the extraction tower and with a stream of regenerated solvent introduced into the tower 56 through a conduit 63, so as to produce, on the one hand, a purified solvent containing almost all of the CO2 present in the demethanized rich solvent, said purified solvent being drawn off at the bottom of the extraction tower 56 by a conduit 58 on which is mounted an expansion valve 60, and, on the other hand, a hydrocarbon solvent enriched in C2 hydrocarbons and more containing little CO2, said solvent being removed at the head of the extraction tower 56 by a conduit 59.
  • the enriched hydrocarbon solvent 59 is introduced into a regeneration column 49 in which said solvent is fractionated by distillation into a fraction of C2 and higher hydrocarbons, which is evacuated at the top of said column 49 by a conduit 48 and constitutes the cut d hydrocarbons C2 and more containing at least 80 mol% of hydrocarbons C3 and more contained in the gas to be treated brought to the washing column 5 by line 3, and in a regenerated hydrocarbon solvent withdrawn from column 49 by a line 50, which regenerated hydrocarbon solvent is recycled by the pump 51, through the refrigerant system 61 and the conduit 57, to the extraction tower 56.
  • the purified solvent circulating in the conduit 58 is introduced into the upper part of a regeneration column 62 provided with a heater 69, in which said purified solvent is subjected to a regeneration comprising a stripping using a stream of inert gas, for example a stream of nitrogen, injected into the lower part of the column 62 through a conduit 43.
  • a stream of inert gas for example a stream of nitrogen
  • Said regeneration produces, on the one hand, a regenerated solvent 34, which is recycled by means of a pump 37 and a pipe 38 to the washing column 5 through the heat exchanger 39 and the pipe 6, and, on the other hand, a stream 44 of acid gas rich in CO2 , which contains almost all of the CO2 present in the demethanized rich solvent and has, expressed in methane equivalent, a hydrocarbon content of less than 10 mol% relative to CO2.
  • Part of the cold regenerated solvent passing through line 38 is diverted through line 63 to be injected into the extraction tower 56 at a point in this tower located above the injection point of the demethanized rich solvent circulating in the line 27.
  • the gaseous mixture to be treated arriving via a pipe 1, is introduced into the lower part of a washing column 5, for example of the type column with plates, in which it is brought into contact, against the current, with a solvent injected into the upper part of the column 5 through a conduit 6, this bringing into contact being carried out at a temperature of, for example, between 0 ° C and -45 ° C.
  • a treated gas consisting mainly of methane and depleted in CO2 is collected, via a line 8, while at the bottom of said column, a liquid phase is drawn off, via line 11, formed of the solvent enriched in CO2 and other compounds absorbed and called rich solvent.
  • the gas mixture to be treated is brought into contact with the solvent in column 5 at an appropriate temperature in the range 0 ° C to -45 ° C and with a ratio of the flow rates of the gas mixture to be treated and of solvent such as on the one hand, the treated gas collected, via line 8, at the head of column 5 has a molar CO2 content of at most equal to 2% and, on the other hand, the rich solvent passing through line 11 contains at least 80 molar% of C3 and higher hydrocarbons present in the gas mixture to be treated.
  • the treated gas, collected by line 8 at the temperature prevailing in the washing column 5, can be delivered to a distribution network after reheating or undergo beforehand, if necessary, one or more additional treatments to perfect its purification.
  • the temperature profile in column 5 is checked by means of the refrigerants 7 through which the liquid medium contained in column 5 passes.
  • the rich solvent circulating in the conduit 11 is introduced, after passing through an expansion valve 12, into the upper part of the demethanization column 17, consisting of a reboiling distillation column 18 and in which the rich solvent is divided into a gaseous phase rich in methane, which is removed at the top of column 17 by a conduit 22, and in a liquid phase depleted in methane, called demethanized rich solvent, which is drawn off at the bottom of column 17 by a conduit 27 .
  • the demethanized rich solvent is brought into a refrigeration zone 64, in which it is cooled to a temperature of, for example, between -25 ° C and -80 ° C and sufficiently lower than the temperature prevailing in the washing zone for cause a demixing of said rich solvent demethanized into two fractions, which separate, in a separator 65, into a lower liquid fraction withdrawn from the separator by a conduit 66, said fraction being called purified solvent and consisting of the solvent containing almost all of the CO2 present in the demethanized rich solvent and having a hydrocarbon content, expressed in methane equivalent, of less than 10 mol% relative to CO2, and in a higher liquid fraction, called C2 and more hydrocarbon fraction and containing at least 80 molar% of C3 and higher hydrocarbons present in the gaseous mixture to be treated arriving via line 1, said hydroc cut arbours being evacuated from the separator 65 by a conduit 48.
  • the purified solvent circulating in the conduit 66 is introduced, after passage through an expansion valve 67, into the upper part of a regeneration column 68 provided with a heater 69, in which the said purified solvent is subjected to regeneration by stripping using a stream of inert gas, for example a stream of nitrogen, injected into the lower part of the column 68 through a pipe 43.
  • a stream of inert gas for example a stream of nitrogen
  • Said regeneration produces, on the one hand, a regenerated solvent 34, which is recycled by means of a pump 37 and a conduit 38 to the washing column 5 through a heat exchanger 39 and the conduit 6, and, on the other hand, a stream 44 of acid gas rich in CO2, which contains almost all of the CO2 present in the demethanized rich solvent and has a hydrocarbon content, expressed in methane equivalent, of less than 10 mol% relative to CO2 .
  • FIG. 3 could also be adapted to include the steps of pretreatment of the gaseous mixture to be treated and demethanization in two stages, which include the embodiments illustrated in FIGS. 1 and 2.
  • the gaseous mixture to be treated arriving via line 1 with a flow rate of 10,000 kmol / h, a temperature of 30 ° C and a pressure of 5,000 kPa was introduced into column 2 for removal of C en and higher hydrocarbons.
  • the gas mixture to be treated being dry, no addition of solvent was carried out via line 41.
  • the pretreated gas mixture was brought into contact with 6000 kmol / h of solvent consisting of a mixture of methanol and water in a molar ratio equal to 95: 5 and having a pressure of 5000 kPa and a temperature equal to -30 ° C. , said contacting being carried out in a washing column 5 comprising 14 plates and operating at -30 ° C under a pressure of 4900 kPa.
  • the refrigerants 7 fitted to the washing column 5 made it possible to maintain the temperature in said column at the desired value.
  • the heated treated gas is directed through line 10 to an expedition pipeline.
  • the demethanization of the rich solvent firstly involved a first expansion of said solvent at a pressure of 3000 kPa, the expanded relaxed solvent supplying the expansion tank 13 in which 362 kmol / h of a first gas containing 68 mol% of methane were produced. , which was discharged at the head of the flask 13 through line 14, and a predemethanized rich solvent withdrawn from said flask through line 15 and whose molar methane content was reduced from 6.11% to 3.57%.
  • the premethanized rich solvent the temperature of which was equal to -33.6 ° C., was expanded in valve 16 and then fed to the distillation column 17 comprising 10 plates and operating at 1800 kPa.
  • the demethanized rich solvent had the following molar composition: . CO2 : 20.16% . Methane : 0.03% . Ethane : 3.37% . Propane : 1.98% . Butane : 1.67% . Methanol : 69.13% . Water : 3.64%
  • the second methane-rich gas was compressed in compressor 20 to the pressure of the first methane-rich gas, namely 3000 kPa.
  • the compressed gas leaving the compressor 20, via the conduit 21, was mixed with the first methane-rich gas to form the methane-rich gas phase 22, which was then compressed, in the compressor 23, until the pressure of the gaseous mixture at treating, namely 5000 kPa, said compressed gas phase being added through line 24, the refrigerant 25 and line 26, to the pretreated gas mixture circulating in line 3.
  • the compressed methane-rich gaseous phase passing through line 26 had a temperature of -20 ° C, a pressure of 5,000 kPa and a flow rate of 938 kmol / h.
  • the molar composition of said methane-rich gas phase flowing in line 26 was as follows: . CO2 : 29.80% . Methane : 59.50% . Ethane : 9.45% . Propane : 0.97% . Butane : 0.26% . Methanol : 0.02%
  • the demethanized rich solvent after expansion in the valve 29 and reheating in the reheating system 28, had a temperature of 10 ° C and a pressure of 800 kPa. Said heated solvent was then divided into a first stream 30 having a flow rate of 4533 kmol / h, which was directed directly to the regeneration column 33, and into a second stream 31, which was heated to 70 ° C. in the heat exchanger. heat 35 before being conveyed to the regeneration column 33.
  • This column operated under a pressure of 700 kPa and included 18 plates, the currents 30 and 31 being injected respectively at the plates 8 and 12, counted from the top of the column.
  • the regeneration column 33 produced at the head a gaseous mixture containing CO2 and the hydrocarbons in C2 and more, which was evacuated via line 42 with a temperature of -14 ° C, a pressure of 700 kPa and a flow rate of 2244 kmol / h and at the bottom a regenerated solvent withdrawn from the regeneration column 33 through the pipe 34.
  • the gas mixture passing through line 42 had the following molar composition: . CO2 : 74.07% . Methane : 0.12% . Ethane : 12.36% . Propane : 7.28% . Butane : 6.13% . Hexane : 0.04%
  • the regenerated solvent is cooled by passage through the heat exchanger 35, then recompressed to a pressure of 5000 kPa by the pump 37, and it is then directed through the conduit 38 on the one hand in a major quantity to the washing column 5 , through the refrigerant 39 and the conduit 6.
  • the gas mixture passing through line 42 was washed against the current in washing tower 47 using a hydrocarbon solvent consisting mainly of hexane.
  • Tower 47 had 35 trays and operated under a pressure of 700 kPa with a temperature of -30 ° C at the head at the level of refrigerant 46.
  • the supply of tower 47 with solvent, via line 53, and in gaseous mixture, through line 42, was carried out respectively on the first plate and on plate 21 of said tower.
  • the washing tower 47 produced at the head a stream of acid gas 44 rich in CO2 and having a hydrocarbon content, expressed in methane equivalent, of less than 10 mol% relative to CO2, said stream of acid gas having a temperature of -30 ° C, a pressure of 650 kPa and a flow rate of 1685 kmol / h, and in the background a hydrocarbon solvent 45 with reduced CO2 content having a temperature of 95.8 ° C, a pressure of 730 kPa and a flow rate of 5059 kmol / h.
  • the molar composition of the acid gas stream 44 was as follows: . CO2 : 98.65% . Methane : 0.15% . Ethane : 0.98% . Butane : 0.05% . Hexane : 0.17%
  • the rich hydrocarbon solvent 45 had the following molar composition: . Ethane : 5.16% . Propane : 3.23% . Butane : 3.69% . Hexane : 87.91%
  • the fractionation of the rich hydrocarbon solvent 45 in column 49 provided with 28 trays and operating under a pressure of 600 kPa produced at the head 561 kmol / h of a cut of hydrocarbons 48 in C2 and more having a temperature of 18 ° C and a pressure of 600 kPa and at the bottom 4500 kmol / h of regenerated hydrocarbon solvent having a temperature of 142.7 ° C and a pressure of 670 kPa, said solvent containing, in mole, 98.89% of hexane and 1.11 % butane.
  • the molar composition of the C2 and higher hydrocarbon cut 48 was as follows: . CO2 : 0.02% . Ethane : 46.49% . Propane : 29.10% . Butane : 24.37% . Hexane : 0.02%
  • Example 2 The pretreatment of said gaseous mixture, in column 2, in order to remove the C6 and higher hydrocarbons therefrom was carried out under the conditions of Example 1 and said column 2 was removed on the one hand, via line 3, a pretreated gas mixture and on the other hand, via line 4, a heavy hydrocarbon fraction having the same composition, temperature, pressure and flow rate characteristics as those of the pretreated gas mixture and of the heavy hydrocarbon fraction obtained in Example 1.
  • the pretreated gas mixture was brought into contact with 11,500 kmol / h of solvent having a temperature of -20 ° C. and a pressure of 5000 kPa and containing, by mole, 82.34% of methanol, 14.67% of water and 2.88 hexane, said contacting being carried out in a washing column 5 comprising 14 plates and operating at -20 ° C under a pressure of 4900 kPa.
  • the refrigerants 7 fitted to the washing column 5 made it possible to maintain the temperature in said column at the desired value.
  • the treated gas, discharged through line 8, was warmed up to ambient temperature in the heat exchanger system 9, the heated treated gas being directed, through line 10, to a shipping pipeline.
  • the demethanization of the rich solvent firstly involved a first expansion of said solvent at a pressure of 3000 kPa, the expanded rich solvent supplying the expansion tank 13 in which 401 kmol / h of a first gas containing 64 mol% of methane, which was removed at the head of the flask 13 via the line 14, and a predemethanized rich solvent withdrawn from the said flask through the line 15 and whose molar methane content has been reduced from 3.70 to 2.01%.
  • the premethanized rich solvent the temperature of which was equal to -22.5 ° C., was expanded in valve 16 and then fed to the distillation column 17 comprising 10 plates and operating at 1800 kPa.
  • the demethanized rich solvent passing through line 27 had the following molar composition: . CO2 : 12.11% . Methane : 0.03% . Ethane : 1.53% . Propane : 1.20% . Butane : 1.01% . Hexane : 2.39% . Methanol : 69.37% . Water : 12.36%
  • the second methane-rich gas was compressed in compressor 20 to the pressure of the first methane-rich gas, namely 3000 kPa.
  • the compressed gas leaving the compressor 20, via the conduit 21, was mixed with the first methane-rich gas to form the methane-rich gas phase 22, which was then compressed, in the compressor 23, until the pressure of the gaseous mixture at treating, namely 5000 kPa, said compressed gas phase being added through line 24, the refrigerant 25 and line 26, to the pretreated gas mixture circulating in line 3.
  • the compressed methane-rich gas phase passing through line 26 had a temperature of -20 ° C, a pressure of 5000 kPa and a flow rate of 1006 kmol / h.
  • the molar composition of said methane-rich gas phase flowing in line 26 was as follows: . CO2 : 34.31% . Methane : 53.50% . Ethane : 9.84% . Propane : 1.70% . Butane : 0.53% . Hexane : 0.09% . Methanol : 0.03%
  • the extraction tower 56 included 31 trays and was supplied on the first tray with 5000 kmol / h of regenerated solvent supplied by line 63 with a temperature of -40 ° C, on tray 21 by the rich demethanized solvent from the system refrigeration 40 and on the plate 31 by the refrigerated hydrocarbon solvent based on hexane supplied by line 57 with a flow rate of 1600 kmol / h.
  • This extraction produced 2079 kmol / h of a rich hydrocarbon solvent having a temperature of -40 ° C and a pressure of 1200 kPa, said rich hydrocarbon solvent being evacuated at the top of tower 56 via line 59, and 18069 kmol / h purified solvent withdrawn from the bottom of said tower, via line 58, at a temperature of -40 ° C. and under a pressure of 1200 kPa.
  • the molar composition of the rich hydrocarbon solvent passing through line 59 was as follows: . CO2 : 0.14% . Methane : 0.13% . Ethane : 9.19% . Propane : 7.79% . Butane : 6.62% . Hexane : 73.72% . Methanol : 2.40%
  • the molar composition of the purified solvent passing through line 58 was as follows: . CO2 : 9.16% . Methane : 0.01% . Ethane : 0.10% . Propane : 0.01% . Hexane : 2.42% . Methanol : 74.91% . Water : 13.40%
  • the C2 and higher hydrocarbon section evacuated via line 48, had the following molar composition: . CO2 : 0.59% . Methane : 0.54% . Ethane : 38.40% . Propane : 32.58% . Butane : 27.67% . Hexane : 0.20% . Methanol : 0.02%.
  • the regenerated hydrocarbon solvent passing through line 50 contained, by mole, 95.77% hexane, 1.11% butane and 3.12% methanol. Said solvent was brought, in the pump 51, to a pressure of 1200 kPa, then refrigerated at -40 ° C in the refrigerant system 61 before being recycled, via the conduit 57, to the extraction tower 56.
  • the purified solvent coming from line 58 of the extraction tower 56 is expanded to a pressure of 200 kPa in the expansion valve 60, then it is introduced into the regeneration column 62 for the purpose of regeneration.
  • Said column 62 comprising 14 plates and operating under a pressure of 200 kPa, is supplied on the first plate with the purified solvent to be regenerated and on the last plate by a stream of nitrogen supplied, via line 43, with a flow rate of 650 kmol / h.
  • the heater 69 which is provided with said column 62, was located on the seventh plate.
  • the stream of CO2-rich acid gas discharged through line 44 had a pressure of 200 kPa and a temperature of -47.5 ° C and it had the following molar composition: . CO2 : 71.64% . Methane : 0.05% . Ethane : 0.77% . Propane : 0.04% . Hexane : 0.40% . Methanol : 0.06% . Nitrogen : 27.04%.
  • the regenerated solvent circulating in the conduit 34 was brought to the pressure of 5000 kPa by passage through the pump 37, then divided into two parts, namely a major part recycled to the washing column 5 after passage through the heat exchanger system 39 and the conduit 6 and a part brought into the extraction tower 56 by the conduit 63.

Landscapes

  • 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)
  • Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
  • Gas Separation By Absorption (AREA)
  • Physical Water Treatments (AREA)
  • Separation Using Semi-Permeable Membranes (AREA)
  • Separation By Low-Temperature Treatments (AREA)
  • Degasification And Air Bubble Elimination (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
EP89403123A 1988-11-15 1989-11-14 Verfahren zur gleichzeitigen Ausscheidung von CO2 und Bearin aus Methan, C2 und höheren Kohlenwasserstoffen und CO2 enthatenden gasförmigen Kohlenwasserstoffen Expired - Lifetime EP0373983B1 (de)

Priority Applications (3)

Application Number Priority Date Filing Date Title
EP93107550A EP0556875B1 (de) 1988-11-15 1989-11-14 Verfahren zur gleichzeitigen Ausscheidung von CO2 und Benzin aus Methan, C2 und höheren Kohlenwasserstoffen und CO2 enthaltenden gasförmigen Kohlenwasserstoffen
AT89403123T ATE100852T1 (de) 1988-11-15 1989-11-14 Verfahren zur gleichzeitigen ausscheidung von co2 und bearin aus methan, c2 und hoeheren kohlenwasserstoffen und co2 enthatenden gasfoermigen kohlenwasserstoffen.
GR950402736T GR3017623T3 (en) 1988-11-15 1995-10-04 Process for the simultaneous elimination of CO2 and gasoline from a gaseous hydrocarbon mixture comprising methane, C2 and higher hydrocarbons and also CO2.

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
FR8814784 1988-11-15
FR888814784A FR2641542B1 (fr) 1988-11-15 1988-11-15 Procede de decarbonatation et de degazolinage simultanes d'un melange gazeux constitue principalement d'hydrocarbures consistant en methane et hydrocarbures en c2 et plus et renfermant egalement co2

Related Child Applications (1)

Application Number Title Priority Date Filing Date
EP93107550.1 Division-Into 1989-11-14

Publications (2)

Publication Number Publication Date
EP0373983A1 true EP0373983A1 (de) 1990-06-20
EP0373983B1 EP0373983B1 (de) 1994-01-26

Family

ID=9371828

Family Applications (2)

Application Number Title Priority Date Filing Date
EP89403123A Expired - Lifetime EP0373983B1 (de) 1988-11-15 1989-11-14 Verfahren zur gleichzeitigen Ausscheidung von CO2 und Bearin aus Methan, C2 und höheren Kohlenwasserstoffen und CO2 enthatenden gasförmigen Kohlenwasserstoffen
EP93107550A Expired - Lifetime EP0556875B1 (de) 1988-11-15 1989-11-14 Verfahren zur gleichzeitigen Ausscheidung von CO2 und Benzin aus Methan, C2 und höheren Kohlenwasserstoffen und CO2 enthaltenden gasförmigen Kohlenwasserstoffen

Family Applications After (1)

Application Number Title Priority Date Filing Date
EP93107550A Expired - Lifetime EP0556875B1 (de) 1988-11-15 1989-11-14 Verfahren zur gleichzeitigen Ausscheidung von CO2 und Benzin aus Methan, C2 und höheren Kohlenwasserstoffen und CO2 enthaltenden gasförmigen Kohlenwasserstoffen

Country Status (14)

Country Link
US (1) US5298156A (de)
EP (2) EP0373983B1 (de)
JP (1) JP2742328B2 (de)
AT (1) ATE124987T1 (de)
AU (1) AU627250B2 (de)
BR (1) BR8907193A (de)
CA (1) CA2002826C (de)
DE (2) DE68923459T2 (de)
ES (2) ES2077452T3 (de)
FR (1) FR2641542B1 (de)
NO (1) NO180687C (de)
RU (1) RU1836407C (de)
UA (1) UA26318A (de)
WO (1) WO1990005766A1 (de)

Families Citing this family (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
NO302567B1 (no) * 1994-02-14 1998-03-23 Norsk Hydro As Mateanordning
FR2743083B1 (fr) * 1995-12-28 1998-01-30 Inst Francais Du Petrole Procede de deshydratation, de desacidification et de degazolinage d'un gaz naturel, utilisant un melange de solvants
JP5383338B2 (ja) * 2009-06-17 2014-01-08 三菱重工業株式会社 Ｃｏ２回収装置及びｃｏ２回収方法
GB201520405D0 (en) * 2015-11-19 2016-01-06 Isis Innovation Ltd And King Abdulaziz City For Science And Technology Hydrocarbon separation process

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3702296A (en) * 1970-12-23 1972-11-07 Atlantic Richfield Co Oil and gas treatment
US3770622A (en) * 1970-12-28 1973-11-06 Fluor Corp Treatment of wet natural gas mixtures to recover liquid hydrocarbons
EP0062789A2 (de) * 1981-03-31 1982-10-20 BASF Aktiengesellschaft Verfahren zur Abtrennung von kondensierbaren aliphatischen Kohlenwasserstoffen und sauren Gasen aus Erdgasen
GB2142041A (en) * 1983-06-24 1985-01-09 El Paso Hydrocarbons Extracting natural gas streams with physical solvents

Family Cites Families (20)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US1838444A (en) * 1930-04-03 1931-12-29 Wehrle Co Towel bar
US1898579A (en) * 1930-05-30 1933-02-21 Union Oil Co Method and apparatus for absorption of constituents from gases and vaporous mixtures
US1972060A (en) * 1930-10-24 1934-08-28 Texas Co Recovery of gasoline from natural gas
US1953043A (en) * 1930-10-24 1934-03-27 Texas Co Recovery of gasoline from natural gas
US2487576A (en) * 1945-11-13 1949-11-08 Phillips Petroleum Co Process for the removal of acidic material from a gaseous mixture
US2930752A (en) * 1952-06-12 1960-03-29 Socony Mobil Oil Co Inc Process for stripping of absorption liquids
US3210270A (en) * 1961-12-01 1965-10-05 Phillips Petroleum Co Fluid separation and gas dehydration process
US3247649A (en) * 1963-04-29 1966-04-26 Union Oil Co Absorption process for separating components of gaseous mixtures
US3347621A (en) * 1964-11-02 1967-10-17 Shell Oil Co Method of separating acidic gases from gaseous mixtures
US3829521A (en) * 1972-07-03 1974-08-13 Stone & Webster Eng Corp Process for removing acid gases from a gas stream
JPS562985B2 (de) * 1975-03-20 1981-01-22
DE2909335A1 (de) * 1979-03-09 1980-09-18 Linde Ag Verfahren und vorrichtung zur zerlegung von erdgas
US4293322A (en) * 1980-04-23 1981-10-06 Helix Technology Corporation Distillative separation of carbon dioxide from hydrogen sulfide
JPS5710378A (en) * 1980-06-19 1982-01-19 Satake Eng Co Ltd Wind supplying and discharging device for cereal grain selector
DE3148475A1 (de) * 1981-02-23 1982-09-23 Gebrüder Bühler AG, 9240 Uzwil "trennvorrichtung fuer getreide und aehnliches korngut"
US4568452A (en) * 1984-06-15 1986-02-04 Exxon Research And Engineering Co. Process for upgrading a contaminated absorbent oil
US4654062A (en) * 1986-07-11 1987-03-31 Air Products And Chemicals, Inc. Hydrocarbon recovery from carbon dioxide-rich gases
US4747858A (en) * 1987-09-18 1988-05-31 Air Products And Chemicals, Inc. Process for removal of carbon dioxide from mixtures containing carbon dioxide and methane
US4775396A (en) * 1987-11-05 1988-10-04 Union Carbide Corporation Selective adsorption of CO2 on zeolites
DE3829878A1 (de) * 1988-09-02 1990-03-08 Metallgesellschaft Ag Verfahren zum behandeln eines kohlenwasserstoffe und h(pfeil abwaerts)2(pfeil abwaerts)s enthaltenden erdgases

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3702296A (en) * 1970-12-23 1972-11-07 Atlantic Richfield Co Oil and gas treatment
US3770622A (en) * 1970-12-28 1973-11-06 Fluor Corp Treatment of wet natural gas mixtures to recover liquid hydrocarbons
EP0062789A2 (de) * 1981-03-31 1982-10-20 BASF Aktiengesellschaft Verfahren zur Abtrennung von kondensierbaren aliphatischen Kohlenwasserstoffen und sauren Gasen aus Erdgasen
GB2142041A (en) * 1983-06-24 1985-01-09 El Paso Hydrocarbons Extracting natural gas streams with physical solvents

Also Published As

Publication number Publication date
NO180687C (no) 1997-05-28
EP0373983B1 (de) 1994-01-26
WO1990005766A1 (fr) 1990-05-31
AU627250B2 (en) 1992-08-20
AU4637589A (en) 1990-06-12
UA26318A (uk) 1999-08-30
EP0556875A2 (de) 1993-08-25
FR2641542B1 (fr) 1994-06-24
BR8907193A (pt) 1991-03-05
NO903128L (no) 1990-09-11
CA2002826A1 (fr) 1990-05-15
NO180687B (no) 1997-02-17
NO903128D0 (no) 1990-07-13
RU1836407C (ru) 1993-08-23
DE68912746T2 (de) 1994-08-11
CA2002826C (fr) 1999-06-29
ES2050833T3 (es) 1994-06-01
DE68923459D1 (de) 1995-08-17
EP0556875A3 (en) 1993-11-10
DE68923459T2 (de) 1996-04-04
FR2641542A1 (fr) 1990-07-13
EP0556875B1 (de) 1995-07-12
ES2077452T3 (es) 1995-11-16
JPH03503779A (ja) 1991-08-22
ATE124987T1 (de) 1995-07-15
JP2742328B2 (ja) 1998-04-22
DE68912746D1 (de) 1994-03-10
US5298156A (en) 1994-03-29

Similar Documents

Publication Publication Date Title
EP0291401B1 (de) Kryogen-Verfahren zur gleichzeitigen selektiven Entschwefelung und Entfernung von Benzin aus einer Gasmischung, die hauptsächlich Methan und auch H2S und C2+Kohlenwasserstoff enthält
US4563202A (en) Method and apparatus for purification of high CO2 content gas
US4370156A (en) Process for separating relatively pure fractions of methane and carbon dioxide from gas mixtures
CA2364354C (fr) Procede et installation pour la recuperation et la purification de l'ethylene produit par pyrolyse d'hydrocarbures, et gaz obtenus par ce procede
CA2357860C (fr) Procede de desacidification d'un gaz par absorption dans un solvant avec un controle de la temperature
EP2452140B1 (de) Verfahren zur herstellung eines methanreichen stroms und c2+kohlenwasserstoffreichen stroms und zugehörige anlage
KR100441039B1 (ko) 천연가스를 액화하고 가공하는 방법 및 장치
EP0848982B1 (de) Verfahren und Vorrichtung zur Gasbehandlung durch Kühlen und Berührung mit einem Lösungsmittel
US4511381A (en) Process for extracting natural gas liquids from natural gas streams with physical solvents
EP0393029A1 (de) Behandlung stickstoffreicher, wasserstofffreier und olefinreicher gas mittels physikalischer lösungsmittel.
EP0395490A1 (de) Verfahren zur Gewinnung von flüssigen Kohlenwasserstoffen und Einrichtung zur Ausführung dieses Verfahrens
FR2873710A1 (fr) Procede pour le traitement d'une charge hydrocarbonee
US4576615A (en) Carbon dioxide hydrocarbons separation process
CA2378677C (fr) Procede ameliore de deshydratation et de degazolinage d'un gaz naturel humide
EP3013924B1 (de) Verfahren zur rückgewinnung eines ethylenstroms aus einem kohlenmonoxidreichen zufuhrstrom
EP0373983B1 (de) Verfahren zur gleichzeitigen Ausscheidung von CO2 und Bearin aus Methan, C2 und höheren Kohlenwasserstoffen und CO2 enthatenden gasförmigen Kohlenwasserstoffen
US4556404A (en) Split-column extractive distillation
US4601738A (en) Process for freeze protection and purification of natural gas liquid product streams produced by the Mehra process
NZ201064A (en) A cryogenic process for removing acidic gases from natural or synthesized gases using low molecular weight esters and ethers
EP0768106B1 (de) Verfahren zur Fraktionierung eines mehrere trennbare Komponenten enthaltenden Fluids wie z.B. Erdgas
US4401560A (en) Process for the separation of aromatic hydrocarbons from petroleum fractions with heat recovery
EP0129704A1 (de) Abtrennung von an Methan reichem Gas, Kohlendioxid und Schwefelwasserstoff aus Gemischen mit leichten Kohlenwasserstoffen
FR2467627A1 (fr) Procede de recuperation d'un liquide volatil present sous forme de vapeur dans une nappe de gaz
US3267028A (en) Separation of wet pyrolysis gases by sorbent treating and fractionation
EP0186555A1 (de) Selbstkühlendes Verfahren zur Extraktion von schweren Kohlenwasserstofffraktionen

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

17P Request for examination filed

Effective date: 19891117

AK Designated contracting states

Kind code of ref document: A1

Designated state(s): AT DE ES FR GB GR IT NL

17Q First examination report despatched

Effective date: 19910111

RAP1 Party data changed (applicant data changed or rights of an application transferred)

Owner name: ELF AQUITAINE PRODUCTION

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): AT DE ES FR GB GR IT NL

REF Corresponds to:

Ref document number: 100852

Country of ref document: AT

Date of ref document: 19940215

Kind code of ref document: T

XX Miscellaneous (additional remarks)

Free format text: TEILANMELDUNG 93107550.1 EINGEREICHT AM 14/11/89.

REF Corresponds to:

Ref document number: 68912746

Country of ref document: DE

Date of ref document: 19940310

ITF It: translation for a ep patent filed
GBT Gb: translation of ep patent filed (gb section 77(6)(a)/1977)

Effective date: 19940418

REG Reference to a national code

Ref country code: ES

Ref legal event code: FG2A

Ref document number: 2050833

Country of ref document: ES

Kind code of ref document: T3

REG Reference to a national code

Ref country code: GR

Ref legal event code: FG4A

Free format text: 3011487

PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT

26N No opposition filed
REG Reference to a national code

Ref country code: FR

Ref legal event code: TP

REG Reference to a national code

Ref country code: GB

Ref legal event code: 732E

NLS Nl: assignments of ep-patents

Owner name: ELF EXPLORATION PRODUCTION

REG Reference to a national code

Ref country code: ES

Ref legal event code: PC2A

REG Reference to a national code

Ref country code: GB

Ref legal event code: IF02

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: AT

Payment date: 20021023

Year of fee payment: 14

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: GR

Payment date: 20021029

Year of fee payment: 14

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: DE

Payment date: 20021104

Year of fee payment: 14

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: ES

Payment date: 20021113

Year of fee payment: 14

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: FR

Payment date: 20021126

Year of fee payment: 14

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: NL

Payment date: 20031028

Year of fee payment: 15

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: GB

Payment date: 20031029

Year of fee payment: 15

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: AT

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20031114

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: ES

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20031115

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: DE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20040602

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: GR

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20040603

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: FR

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20040730

REG Reference to a national code

Ref country code: FR

Ref legal event code: ST

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: GB

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20041114

REG Reference to a national code

Ref country code: ES

Ref legal event code: FD2A

Effective date: 20031115

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: NL

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20050601

GBPC Gb: european patent ceased through non-payment of renewal fee

Effective date: 20041114

NLV4 Nl: lapsed or anulled due to non-payment of the annual fee

Effective date: 20050601

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IT

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES;WARNING: LAPSES OF ITALIAN PATENTS WITH EFFECTIVE DATE BEFORE 2007 MAY HAVE OCCURRED AT ANY TIME BEFORE 2007. THE CORRECT EFFECTIVE DATE MAY BE DIFFERENT FROM THE ONE RECORDED.

Effective date: 20051114