EP1532228B1 - Verfahren zur umwandlung von methanhaltigen gasförmigen kohlenwasserstoffgemischen in flüssige kohlenwasserstoffe - Google Patents
Verfahren zur umwandlung von methanhaltigen gasförmigen kohlenwasserstoffgemischen in flüssige kohlenwasserstoffe Download PDFInfo
- Publication number
- EP1532228B1 EP1532228B1 EP02807530A EP02807530A EP1532228B1 EP 1532228 B1 EP1532228 B1 EP 1532228B1 EP 02807530 A EP02807530 A EP 02807530A EP 02807530 A EP02807530 A EP 02807530A EP 1532228 B1 EP1532228 B1 EP 1532228B1
- Authority
- EP
- European Patent Office
- Prior art keywords
- methane
- product
- zone
- hydrocarbon
- line
- 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.)
- Expired - Lifetime
Links
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 title claims abstract description 292
- 229930195733 hydrocarbon Natural products 0.000 title claims abstract description 133
- 150000002430 hydrocarbons Chemical class 0.000 title claims abstract description 133
- 239000004215 Carbon black (E152) Substances 0.000 title claims abstract description 96
- 239000000203 mixture Substances 0.000 title claims abstract description 52
- 238000000034 method Methods 0.000 title claims abstract description 47
- 239000007788 liquid Substances 0.000 title claims abstract description 26
- 238000005336 cracking Methods 0.000 claims abstract description 66
- 239000003345 natural gas Substances 0.000 claims abstract description 35
- 239000001257 hydrogen Substances 0.000 claims abstract description 34
- 229910052739 hydrogen Inorganic materials 0.000 claims abstract description 34
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 claims abstract description 30
- 239000003054 catalyst Substances 0.000 claims abstract description 17
- 229930195735 unsaturated hydrocarbon Natural products 0.000 claims abstract description 16
- 230000002378 acidificating effect Effects 0.000 claims abstract description 15
- 239000000047 product Substances 0.000 claims description 75
- 238000000926 separation method Methods 0.000 claims description 61
- 239000007789 gas Substances 0.000 claims description 33
- 230000029936 alkylation Effects 0.000 claims description 28
- 238000005804 alkylation reaction Methods 0.000 claims description 28
- 229910021536 Zeolite Inorganic materials 0.000 claims description 4
- 239000007795 chemical reaction product Substances 0.000 claims description 4
- HNPSIPDUKPIQMN-UHFFFAOYSA-N dioxosilane;oxo(oxoalumanyloxy)alumane Chemical compound O=[Si]=O.O=[Al]O[Al]=O HNPSIPDUKPIQMN-UHFFFAOYSA-N 0.000 claims description 4
- 239000010457 zeolite Substances 0.000 claims description 4
- 238000004064 recycling Methods 0.000 claims description 2
- 238000006243 chemical reaction Methods 0.000 abstract description 13
- 239000008246 gaseous mixture Substances 0.000 abstract description 2
- 239000012263 liquid product Substances 0.000 description 15
- 125000004432 carbon atom Chemical group C* 0.000 description 12
- 230000006835 compression Effects 0.000 description 10
- 238000007906 compression Methods 0.000 description 10
- 230000015572 biosynthetic process Effects 0.000 description 7
- 239000000571 coke Substances 0.000 description 7
- 238000004519 manufacturing process Methods 0.000 description 7
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 6
- 238000007796 conventional method Methods 0.000 description 6
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 description 5
- 150000001336 alkenes Chemical class 0.000 description 5
- 150000001345 alkine derivatives Chemical class 0.000 description 5
- OFBQJSOFQDEBGM-UHFFFAOYSA-N n-pentane Natural products CCCCC OFBQJSOFQDEBGM-UHFFFAOYSA-N 0.000 description 5
- 229920006395 saturated elastomer Polymers 0.000 description 5
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 description 4
- 150000001335 aliphatic alkanes Chemical class 0.000 description 4
- 150000004945 aromatic hydrocarbons Chemical class 0.000 description 4
- 238000004821 distillation Methods 0.000 description 4
- 150000002431 hydrogen Chemical class 0.000 description 4
- 239000012528 membrane Substances 0.000 description 4
- -1 C1 - C4 Chemical class 0.000 description 3
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical compound OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 description 3
- 239000003377 acid catalyst Substances 0.000 description 3
- 229910002092 carbon dioxide Inorganic materials 0.000 description 3
- 239000001569 carbon dioxide Substances 0.000 description 3
- 239000003085 diluting agent Substances 0.000 description 3
- 239000000463 material Substances 0.000 description 3
- 239000000376 reactant Substances 0.000 description 3
- 238000005057 refrigeration Methods 0.000 description 3
- 238000001179 sorption measurement Methods 0.000 description 3
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 2
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 2
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 description 2
- KRHYYFGTRYWZRS-UHFFFAOYSA-N Fluorane Chemical compound F KRHYYFGTRYWZRS-UHFFFAOYSA-N 0.000 description 2
- QAOWNCQODCNURD-UHFFFAOYSA-N Sulfuric acid Chemical compound OS(O)(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-N 0.000 description 2
- HSFWRNGVRCDJHI-UHFFFAOYSA-N alpha-acetylene Natural products C#C HSFWRNGVRCDJHI-UHFFFAOYSA-N 0.000 description 2
- 229910052799 carbon Inorganic materials 0.000 description 2
- 238000004939 coking Methods 0.000 description 2
- 230000003247 decreasing effect Effects 0.000 description 2
- 125000002534 ethynyl group Chemical group [H]C#C* 0.000 description 2
- 229910000037 hydrogen sulfide Inorganic materials 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 239000001294 propane Substances 0.000 description 2
- 238000000197 pyrolysis Methods 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 229910001868 water Inorganic materials 0.000 description 2
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 description 1
- VGGSQFUCUMXWEO-UHFFFAOYSA-N Ethene Chemical compound C=C VGGSQFUCUMXWEO-UHFFFAOYSA-N 0.000 description 1
- 239000005977 Ethylene Substances 0.000 description 1
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 description 1
- 239000002253 acid Substances 0.000 description 1
- 230000006978 adaptation Effects 0.000 description 1
- 150000001491 aromatic compounds Chemical class 0.000 description 1
- 125000004429 atom Chemical group 0.000 description 1
- 239000001273 butane Substances 0.000 description 1
- 229910002091 carbon monoxide Inorganic materials 0.000 description 1
- 238000004523 catalytic cracking Methods 0.000 description 1
- 238000006555 catalytic reaction Methods 0.000 description 1
- 238000001816 cooling Methods 0.000 description 1
- 230000003111 delayed effect Effects 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 239000000446 fuel Substances 0.000 description 1
- VUZPPFZMUPKLLV-UHFFFAOYSA-N methane;hydrate Chemical compound C.O VUZPPFZMUPKLLV-UHFFFAOYSA-N 0.000 description 1
- IJDNQMDRQITEOD-UHFFFAOYSA-N n-butane Chemical compound CCCC IJDNQMDRQITEOD-UHFFFAOYSA-N 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
- 230000003647 oxidation Effects 0.000 description 1
- 238000007254 oxidation reaction Methods 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 230000000135 prohibitive effect Effects 0.000 description 1
- 238000010791 quenching Methods 0.000 description 1
- 230000000171 quenching effect Effects 0.000 description 1
- 229930195734 saturated hydrocarbon Natural products 0.000 description 1
- 239000011593 sulfur Substances 0.000 description 1
- 229910052717 sulfur Inorganic materials 0.000 description 1
- 239000002912 waste gas Substances 0.000 description 1
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
- C10G51/00—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more cracking processes only
- C10G51/06—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more cracking processes only plural parallel 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
- C10G29/00—Refining of hydrocarbon oils, in the absence of hydrogen, with other chemicals
- C10G29/20—Organic compounds not containing metal atoms
- C10G29/205—Organic compounds not containing metal atoms by reaction with hydrocarbons added to the hydrocarbon oil
-
- 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
- C10G57/00—Treatment of hydrocarbon oils, in the absence of hydrogen, by at least one cracking process or refining process and at least one other conversion process
- C10G57/005—Treatment of hydrocarbon oils, in the absence of hydrogen, by at least one cracking process or refining process and at least one other conversion process with alkylation
Definitions
- This invention relates to an improved method of converting mixtures comprising major amounts of methane and minor amounts of normally gaseous higher hydrocarbons to normally liquid hydrocarbons. More particularly, the invention relates to an improved method of converting at least a substantial portion of methane-containing gaseous hydrocarbon mixtures to liquid hydrocarbons.
- Natural gas is typically a mixture of about 70 mole percent to about 98 mole percent of methane mixed with heavier hydrocarbons. These heavier hydrocarbons are mostly alkanes of two or more carbon atoms present in decreasing amounts according to increasing carbon number. Although these heavier hydrocarbons are typically present in small quantities relative to the methane and other normal gaseous materials such as carbon dioxide and even hydrogen sulfide are often present, as used herein, the term "natural gas" refers to a mixture which is predominately methane with from about 2 mole percent to about 30 mole percent of other normally gaseous hydrocarbons, e.g., ethane, propane and butane. Removal of any other materials, such as carbon dioxide or water, if necessary, is accomplished by conventional methods.
- Natural gas is an important energy source throughout much of the developed world including the United States. Particularly important is the use of nature gas as an energy source in its property of clean burning without the co-production of environmentally damaging oxides of nitrogen and sulfur. Unfortunately, the location of natural gas usage is often distant from the location of natural gas production so that transportation of the natural gas as by pipeline, or electrical energy produced therefrom, is often difficult and/or prohibitive because of the cost of such transportation.
- a process of converting a normally gaseous, methane-containing, hydrocarbon feed to a normally liquid hydrocarbon product which comprises:
- the low temperature cracking zone is operated at a temperature of from about 900°K to about 1400° K and a pressure from about 0.5 bar to about 10 bars.
- the high temperature cracking zone is operated at a temperature of from about 1450°K to about 1500°K and a pressure from about 0.5 bar to about 10 bars.
- the methane-containing hydrocarbon mixture is natural gas.
- the alkylation zone operates at a temperature of from about 300°K to about 800°K and a pressure from about 2 bars to about 30 bars
- the acidic catalyst is an acidic zeolite catalyst.
- the methane-containing hydrocarbon feed is natural gas of from about 70 mole percent to about 98 mole percent methane.
- the residence time in the low temperature cracking zone is from about 1 millisecond to about 500 milliseconds and the residence time in the high temperature cracking zone is from about 1 millisecond to about 100 milliseconds.
- the preferred embodiments of the present invention provide an improved method or process for the conversion of methane-containing gaseous hydrocarbon mixtures into normally liquid hydrocarbons of increased ease of transportation.
- the process includes the separation of the methane component of the methane-containing gaseous hydrocarbon mixture from the heavier hydrocarbon component.
- this heavier hydrocarbon component is subjected to cracking at a relatively low cracking temperature sufficient to crack the heavier hydrocarbons, but not crack an appreciable quantity of methane. This low temperature cracking process minimizes the loss of heavier hydrocarbons as by coking with a resulting overall efficiency of liquid product formation.
- the methane-containing gaseous hydrocarbon mixtures to which the invention relates may include natural gas and also the light gases that are produced in petroleum refinery operations such as catalytic cracking and delayed coking. Gaseous hydrocarbon mixtures resulting from these operations are typically separated to recover the heavier, more valuable components with the light ends being used for fuel. Such streams often contain a significant portion of ethane, propane, alkanes and alkynes and hydrogen in addition to methane. The process of the invention is useful to convert these "waste gas" streams to more valuable liquid products.
- the methane-containing gaseous hydrocarbon mixtures to which the process of the invention applies are those normally gaseous hydrocarbon mixtures containing at least about 40 mole percent methane and preferably at least about 55 mole percent methane with the remainder comprising saturated and unsaturated hydrocarbons as well as hydrogen.
- natural gas is natural gas. Natural gas, as obtained from the ground, often contains non-hydrocarbon materials such as water, hydrogen sulfide and carbon dioxide.
- natural gas is used to describe a mixture of about 70 mole percent to about 98 mole percent of methane with the remainder being heavier hydrocarbons, mostly alkanes, of two or more carbon atoms present in decreasing amounts according to increasing carbon number.
- At least a major proportion of the separated methane is separately cracked in the substantial absence of the heavier hydrocarbon component of the natural gas feed. Remaining portions of the separated methane are reacted with unsaturated hydrocarbons in the presence of an acid catalyst to produce the normally liquid hydrocarbon product as illustrated by the above equations.
- the separated methane is not cracked but is in part used for the acid-catalyzed reaction of methane with cracked heavier hydrocarbons with any methane not so employed being removed from the process system and sent to disposal or used in the production of thermal or electrical energy as by conventional methods. Such energy is useful in portions of the overall process of the invention or in other applications.
- a novel method of separating the methane portion of the natural gas feed from the heavier hydrocarbon component is employed.
- a methane-containing gaseous hydrocarbon feed is separated into a predominately methane portion and a predominately heavier hydrocarbon portion.
- the higher hydrocarbon portion is cracked at a relatively low cracking temperature, pressurized and separated into a hydrogen product and a hydrocarbon product.
- the hydrocarbon product is combined with the methane separated from the natural gas feed and the mixture is reacted in the presence.of an acidic catalyst.
- the resulting reaction product is separated intro a lighter stream of predominately hydrogen and methane, a portion of which is vented with the remainder being recycled.
- the heavier portion of the reaction product is the desired normally liquid product.
- FIG. 4 A novel separation procedure, not forming part of the invention, is shown in Figure 4 .
- This procedure serves to separate the methane components of a methane-containing gaseous hydrocarbon feed from the heavier hydrocarbon component and is particularly, but not exclusively, employed in the processes of Figures 2 and 3 .
- a methane-containing gaseous hydrocarbon feed is cooled by recycle streams and optionally by refrigeration before passing to a high pressure separator.
- the resulting high pressure separation produces an overhead vapor mixture of predominately methane and a bottoms liquid stream of heavier hydrocarbons.
- the overhead vapor stream is depressurized to cool the stream and condense at least a portion of any heavier hydrocarbon present.
- This condensed hydrocarbon portion of the high pressure separator overhead is separated from methane present by means of a low pressure separator and then is combined with the liquid effluent of the high pressure separator which has undergone depressurization.
- the cool liquid hydrocarbon stream and the cool gaseous methane stream are used to cool the incoming natural gas feed as by cross-exchange.
- the present invention provides an improved process for the conversion of normally gaseous methane-containing hydrocarbons such as natural gas to normally liquid hydrocarbon product which is of particular value because of the ease of its transportation.
- normally gaseous methane-containing hydrocarbons such as natural gas
- normally liquid hydrocarbon product which is of particular value because of the ease of its transportation.
- the cracking of natural gas, in a pyrolysis unit or other conventional apparatus, followed by processing operations to increase the production of normally liquid product is known but has some inherent difficulties.
- the cracking of methane-containing gaseous hydrocarbons such as natural gas taken as a whole requires the use of relatively high temperatures in order to crack the methane of the gaseous mixture. Under these relatively high-temperature conditions, a significant percentage of the higher hydrocarbon portion of the methane-containing gaseous hydrocarbons is effectively lost through formation of coke or other undesirable reactions.
- the methane which is not cracked is also useful as a diluent or energy source and is also a reactant in the conversion of alkenes and alkynes resulting from cracking of methane as well as from cracking the heavier hydrocarbon portion of the gaseous feed.
- methane and higher hydrocarbon reactants there is a need for methane and higher hydrocarbon reactants.
- methane component of the methane-containing gaseous hydrocarbon feed from the heavier hydrocarbon component and to crack the higher hydrocarbon component under conditions of temperature and pressure sufficient to cause cracking of the higher hydrocarbons but insufficient to cause substantial coke formation.
- the methane component in some embodiments of the invention is separately cracked at relatively high temperatures. In such embodiments, the products of the two crackers are combined for further processing.
- the methane component of the natural gas feed is not separately cracked but is in part used as a reactant in a subsequent portion of the overall process with an excess methane being available for energy production or other purposes.
- the conditions of the cracking zone include a temperature above about 1450°K, preferably from about 1500°K to about 1900° K and a pressure from about 0.5 bar to about 10 bars, preferably from about 1 bar to about 3 bars.
- the residence time in the cracking zone is from about 1 millisecond to about 100 milliseconds.
- the cracking zone operates at a temperature from about 900° K to about 1400°K, preferably from about 1100° K to about 1250° K, and a pressure from about 0.5 bar to about 10 bars, preferably from about 1 bar to about 3 bars.
- the residence time within this low-temperature cracking zone is from about 1 millisecond to about 500 milliseconds, preferably from about 10 milliseconds to about 100 milliseconds.
- the effluent from the heavier hydrocarbon cracking zone, with or without being mixed with the effluent of a methane cracking zone is compressed by a compressor or other conventional method to facilitate removal of non-hydrocarbons such as hydrogen upon passage to a cracked gas separation zone wherein the hydrocarbons are separated into an overhead fraction comprising primarily hydrogen and a bottoms fraction comprising primarily methane and unsaturated hydrocarbons, e.g. alkenes and alkynes.
- This separation is conducted by conventional methods such as cryogenic distillation, pressure swing adsorption, or a selectively permeable membrane.
- the operating conditions of the separation zone are dictated by the chosen technique.
- the overhead product is principally hydrogen and is recycled to a cracking zone or is removed from the system for disposal or energy use.
- the heavier or bottoms product from the cracked gas separation zone is mixed with a portion of the methane-containing gaseous hydrocarbon feed or methane obtained by separation of the components of that feed.
- This mixture is passed to an alkylation zone where the mixture is contacted with an acid alkylation catalyst.
- catalysts are conventional and well-known and include hydrofluoric acid and sulfuric acid.
- Preferred acid catalysts are acidic zeolite catalysts, also conventional, and particularly preferred is the acidic zeolite catalyst H-ZSM-5.
- the alkylation zone is operated at a reaction temperature of from about 300°K to about 800°K, preferably from about 500°K to about 700°K, and a pressure from about 2 bars to about 30 bars, preferably from about 5 bars to about 15 bars.
- the liquid product is separated in a conventional liquid product separation zone by conventional methods such as distillation or membrane separation.
- the heavier or bottoms product is the desired normally liquid product comprising saturated or aromatic hydrocarbons of 4 or more carbon atoms, most frequently from 4 to 12 carbon atoms inclusive.
- the lighter product of the liquid product zone comprises hydrogen, methane and small portions of C 2 - C 4 hydrocarbons.
- the light product is principally recycled to the cracked products separation zone with lesser portions being recycled to a methane high-temperature cracking zone or removed from the system for disposal or energy use.
- the product of cracking zone II is passed by line 104 to a compression zone III, typically a compressor, which, if necessary, increases the pressure of the product stream. If the cracking zone product is at a suitable pressure, the compression step can be omitted.
- the product stream is then passed by line 105 to mix with a recycle stream of hydrogen and hydrocarbons in the C 1 - C 4 range shown as line. 163.
- the combined streams 105 and 163, now stream 106, are passed to a separation zone IV shown as a membrane system but which also could use other methods such as refrigeration, distillation, or pressure swing adsorption.
- the hydrogen overhead from the separation zone IV passes by line 131 to where it is split with a portion, line 141, going to disposal or use as an energy source and the remainder going by line 132 to a compression zone VII, typically a compressor, where the pressure is increased to approximately that of the inlet gas feed with which it is mixed.
- the mixture returns to the cracking zone II by lines 133 and 103.
- the bottom product of the separation zone IV is a mixture of methane, hydrogen, recycled alkanes, and unsaturated hydrocarbons of two or more carbon atoms.
- This product leaves the zone by line 107, is combined with the minor portion of the natural gas feed, line 121, and the mixture passes by line 108 to a alkylation zone V where the methane present reacts with the unsaturated hydrocarbons in the presence of an acidic alkylation catalyst to produce a mixture of hydrogen and a range of hydrocarbon products of up to about 20 carbon atoms.
- This mixture passes by line 109 to a separation zone VI where it is separated into an overhead product of hydrogen and C 1 - C 4 hydrocarbons exiting by line 161. A portion of this overhead is removed by line 171 for disposal or energy use.
- separation zone VI The major portion of the overhead product of separation zone VI passes by line 162 to a compression zone VIII, typically a compressor, where the pressure is raised to one compatible with separation zone IV.
- compression zone VIII typically a compressor
- the light gas leaves the compressor by line 163 to where it is combined with gas from the cracking zone II and the mixture is sent by line 106 to separation zone IV.
- the bottom product of separation zone VI, line 110 is the desired normally liquid product comprising a range of hydrocarbons from C 4 to C 12 and higher.
- methane-containing gaseous hydrocarbon feed is introduced by line 1 where a split sends a minor portion by line 21 for use in an alkylation zone D.
- the remainder of the inlet gaseous hydrocarbon feed is sent by line 2 to an inlet gas separation zone J where the methane is substantially separated from the higher hydrocarbon portion of the feed.
- This separator can be a conventional unit such as a cryogenic demethanizer, but also is suitably a unit such as that illustrated by Fig. 5.
- the overhead of the inlet gas separation zone J exits by line 91, where it is split, a portion of which, line 96, is mixed with some of the inlet gas, line 21, and fed to the alkylation zone D by lines 22 and 8.
- the remainder of the light gas from the inlet separation zone J, line 92, combines with a recycle stream, line 51, and then passes by line 93 to a relatively high temperature cracking zone H where the methane is cracked to produce hydrogen and some unsaturated hydrocarbons.
- the bottom product of inlet gas separation zone J exits by line 95 and is mixed with the recycle gas of line 34.
- the combined streams are passed by line 3 to a relatively low temperature cracking zone A where the heavier hydrocarbon component of the gaseous hydrocarbon feed is cracked at the relatively low cracking temperature with relatively little coke formation.
- the effluent from the low temperature cracking zone exits by line 4 to where it is combined with the effluent of the high temperature cracking zone H, line 94, and the mixture passes by line 11 to a compression zone B, typically a compressor.
- the compressed mixture, line 5 is mixed with recycled gas, line 63, and the mixture is sent through line 6 to cracked products separation zone C.
- This separation zone is conventional and is suitably a membrane system, a cryogenic distillation unit or a pressure swing adsorption system.
- the overhead from the separation zone C primarily hydrogen with some methane, exits by line 31. This mixture is split with a portion removed through line 41 for disposal or energy use.
- the remainder of the separation zone C overhead passes by line 32 to a compression zone F, typically a compressor, where the pressure is raised to approximately that of the inlet gas.
- the exiting mixture passes by line 33 to where it is split, with one portion being sent by line 51, mixed with inlet gas separation zone J overhead, line 92, and then going by line 93 to the relatively high temperature cracking zone H.
- the remainder of stream 33 passes by line 34 to where it is mixed with the bottom product of inlet gas separation zone J, introduced by line 95, and the mixture is sent to the relatively low temperature cracking zone A by line 3.
- This bottom product is the desired liquid product containing saturated and aromatic hydrocarbons of 4 or more carbon atoms, most typically from 4 to 12 carbon atoms inclusive.
- the overhead product of the alkylatoin zone separator E exits by line 61 to where it is split, with a portion passing by line 71 to disposal or energy use and the remainder, line 62, is compressed at compression zone G, typically a compressor, to a pressure approximating that of cracked gas separation zone C.
- the compressed product, line 63 is mixed with combined cracking zone effluent, line 5, and the mixture is transferred to the cracked gas separation zone C by line 6.
- Fig. 3 represents a somewhat different embodiment of the invention.
- the methane component of the methane-containing gaseous hydrocarbon feed is separated from the heavier hydrocarbon component.
- This heavier hydrocarbon component is cracked in a relatively low temperature cracking zone as in other embodiments but the methane component is not cracked. Instead, a portion of the methane is employed to react in the alkylation zone D with unsaturated hydrocarbons from cracked gas separation zone C. The remainder of the methane is utilized as a source of thermal or electrical energy in this or other processes.
- a methane-containing gaseous hydrocarbon feed is separated in inlet gas separation zone J by conventional means or by the novel procedure of Fig. 5.
- the overhead of the inlet gas separation zone is primarily methane which is transferred by line 21 for subsequent reaction with unsaturated hydrocarbons of cracked gas separation zone C in the cracked products alkylation zone D.
- the heavier product from inlet gas separation zone J comprises the heavier hydrocarbon portion of its gaseous feeds This product exits the separation zone by line 2, is combined with recycle gas from stream 33 and passes by line 3 to a low temperature cracking zone A wherein the heavier hydrocarbon component is converted largely to alkenes and alkynes.
- the unsaturated hydrocarbon mixture exits, line 4, and is elevated in pressure by compression zone B, typically a compressor, to a pressure approximating that of cracked gas separation zone C.
- compression zone B typically a compressor
- the compressed gas is sent by line 5 to where it combines with recycle gas, line 63, and is transferred via line 6 to cracked products separation zone C.
- the overhead product of this separation zone, line. 31, is largely hydrogen with a lesser amount of ethane.
- a portion of this overhead product is removed by line 41 for disposal or energy use and the remainder, stream 32, is increased in pressure by compression zone F, typically a compressor, to that approximating the pressure of the low temperature cracking zone and then is transferred by lines 33 and 3 to the low temperature cracking zone A.
- the bottoms product of cracked products separation zone C, exiting by line 7, comprises a mixture of unsaturated hydrocarbons.
- This mixture is mixed with gaseous feed, stream 21, and is transported by line 8 to alkylation zone D wherein the unsaturated hydrocarbons react with methane in the presence of an acidic catalyst.
- the resulting product mixture is sent to alkylation product separation zone E by line 9.
- the light overhead of alkylation product separation zone E exits by line 61. This overhead, largely methane and hydrogen with minor amounts of C 2 - C 4 hydrocarbon, is then split. One portion is removed as a stream. 71 for disposal or energy use.
- stream 62 is pressurized at compression zone G, typically a compressor, to a pressure approximately that of cracked gas separation zone C and passes by line 63 to where it is mixed with effluent from low temperature cracking zone A and returned by line 6 to separation zone C.
- compression zone G typically a compressor
- the bottoms product of alkylation product separation zone E, exiting by line 10, is the desired normally liquid hydrocarbon mixture of saturated and aromatic hydrocarbons of 4 or more carbon atoms, more typically 4 to 12 carbon atoms inclusive.
- Figure 4 represents a novel and preferred method of separating the methane component of a methane-containing gaseous hydrocarbon mixture inlet feed from the heavier hydrocarbon component.
- This separation system comprises its use as an inlet feed separator in the process of Figures 2 and 3 .
- the use of the separation system of Figure 4 is not limited to such processes and it is broadly applicable to other separations of methane from heavier hydrocarbons such as ethane.
- the high pressure gaseous hydrocarbon feed typically at a pressure of from about 20 bars to about 100 bars, passes by lines 201 ,202, .203 and 204 in which it is cooled, as described below, into a high pressure separation zone K operated at a temperature of from about 200°K to about 270°K.
- a high pressure separation zone K operated at a temperature of from about 200°K to about 270°K.
- the feed is separated into an overhead vapor stream 205 comprising predominately methane, and a bottoms liquid stream 211 which comprises the large majority of the ethane and the other heavier hydrocarbons of the gaseous hydrocarbon feed.
- the vapor stream 205 is depressurized typically across a valve or turboexpander to a pressure of from about 5 bars to about 20 bars with the temperature being cooled from about 100°K to about 200°K due to the expansion of the vapor.
- the pressure drop causes additional hydrocarbons of two or more carbon atoms to condense as the mixture passes by line 206 to a low pressure separation zone M.
- a cold vapor, stream 207 is obtained as overhead from the high pressure separation zone and is routed to high pressure/low pressure cross-exchangers C-2 and A-2 to provide cooling and thereby reduce the temperature of the feed.
- the liquid bottoms product of high pressure separation zone K passes by line 211 to a depressurization zone N, typically an expansion valve, to reduce the pressure on the liquid.
- the reduced pressure fluid passes by line 212 to where it is mixed with the bottoms product of the low pressure separation zone M, line 213, and the resulting mixture is sent by line 214 to heat exchanger A-3 where it, together with the vapor of line 208 from cross-exchanger C-2 is used to reduce the temperature of the inlet gas feed.
- the heat exchangers at A-1 (together with A-2 and A-3) and at C-1 (taken with C-2) are often sufficient to effect the desired reduction of gaseous hydrocarbon inlet feed. If desired, however, additional temperature reduction is obtained by employing optional refrigeration at exchanger B.
- the outlet lines from the overall separation process, lines 209 and 215, comprise the methane component and the stream containing the heavier hydrocarbon component of the gaseous hydrocarbon inlet feed, respectively.
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)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
Claims (7)
- Verfahren zur Umwandlung eines normal gasförmigen, methanhaltigen Kohlenwasserstoffrohmaterials in ein normal flüssiges Kohlenwasserstoffprodukt, das umfasst:a) Separieren der Methankomponente des Rohmaterials von der schwereren Kohlenwasserstoffkomponente,b) Cracken der schwereren Kohlenwasserstoffkomponente des Rohmaterials bei einer relativ niedrigen Temperatur in einer Crackzone mit niedriger Temperatur,c) wahlweise Cracken eines Teils der Methankomponente des Rohmaterials bei einer relativ hohen Temperatur in einer Crackzone mit hoher Temperatur,d) Weiterleiten des Ausflusses aus der Crackzone mit niedriger Temperatur, vermischt mit einem beliebigen Ausfluss aus einer Crackzone mit hoher Temperatur, in eine Crackgas-Separationszone, worin eine leichte Fraktion hergestellt wird, die Wasserstoff und eine schwerere Wasserstofffraktion umfasst, ungesättigte Kohlenwasserstoffe umfassend,e) Weiterleiten der schwereren Kohlenwasserstofffraktion, gemischt mit Methan, in eine Alkylierungszone, worin das schwerere Kohlenwasserstoffprodukt bei Vorhandensein eines sauren Alkylierungskatalysators zur Reaktion mit dem Methan gebracht wird,f) Separieren der resultierenden Alkylierungszonenreaktionsprodukte in einem Flüssigzonenproduktseparator, um eine leichte Produktmischung und ein schwereres Produkt von normal flüssigem Kohlenwasserstoff herzustellen, undg) Rezyklierung eines Teils des leichten Produkts des Alkylierungszonenproduktseparators.
- Verfahren nach Anspruch 1, wobei die Crackzone mit niedriger Temperatur bei einer Temperatur von zwischen 900°K und 1400°K und einem Druck zwischen 0,5 bar und 10 bar gehandhabt wird.
- Verfahren nach Anspruch 1 oder 2, wobei die Crackzone mit hoher Temperatur bei einer Temperatur von zwischen 1450°K und 1500°K und einem Druck zwischen 0,5 bar und 10 bar gehandhabt wird.
- Verfahren nach einem der vorangehenden Ansprüche, wobei die methanhaltige Kohlenwasserstoffmischung Erdgas ist.
- Verfahren nach einem der vorangehenden Ansprüche, wobei die Alkylierungszone bei einer Temperatur von zwischen 300°K und 800°K und einem Druck zwischen 2 bar und 30 bar arbeitet und der saure Katalysator ein saurer Zeolith-Katalysator ist.
- Verfahren nach einem der vorangehenden Ansprüche, wobei das methanhaltige Kohlenwasserstoffrohmaterial Erdgas mit zwischen 70 Molprozent und 98 Molprozent Methan ist.
- Verfahren nach einem der vorangehenden Ansprüche, wobei die Verweilzeit in der Crackzone mit niedriger Temperatur zwischen 1 Millisekunde und 500 Millisekunden dauert und die Verweilzeit in der Crackzone mit hoher Temperatur zwischen 1 Millisekunde und 100 Millisekunden dauert.
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
PCT/US2002/019026 WO2003106593A1 (en) | 2000-06-09 | 2002-06-14 | Method for converting methane-containing gaseous hydrocarbon mixtures to liquid hydrocarbons |
Publications (3)
Publication Number | Publication Date |
---|---|
EP1532228A1 EP1532228A1 (de) | 2005-05-25 |
EP1532228A4 EP1532228A4 (de) | 2006-08-16 |
EP1532228B1 true EP1532228B1 (de) | 2011-12-14 |
Family
ID=34215282
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
EP02807530A Expired - Lifetime EP1532228B1 (de) | 2002-06-14 | 2002-06-14 | Verfahren zur umwandlung von methanhaltigen gasförmigen kohlenwasserstoffgemischen in flüssige kohlenwasserstoffe |
Country Status (4)
Country | Link |
---|---|
EP (1) | EP1532228B1 (de) |
AT (1) | ATE537241T1 (de) |
AU (1) | AU2002368018B2 (de) |
CA (1) | CA2489383C (de) |
Families Citing this family (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN113444553B (zh) * | 2020-03-27 | 2023-01-03 | 中国石油化工股份有限公司 | 脱除天然气制乙炔系统挥发性有机物的装置及方法 |
Family Cites Families (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
GB2191212B (en) * | 1986-06-05 | 1990-02-07 | British Petroleum Co Plc | Integrated process for the production of liquid hydrocarbons from methane |
US5012028A (en) * | 1986-07-11 | 1991-04-30 | The Standard Oil Company | Process for upgrading light hydrocarbons using oxidative coupling and pyrolysis |
US6130260A (en) * | 1998-11-25 | 2000-10-10 | The Texas A&M University Systems | Method for converting natural gas to liquid hydrocarbons |
-
2002
- 2002-06-14 AU AU2002368018A patent/AU2002368018B2/en not_active Ceased
- 2002-06-14 CA CA2489383A patent/CA2489383C/en not_active Expired - Fee Related
- 2002-06-14 AT AT02807530T patent/ATE537241T1/de active
- 2002-06-14 EP EP02807530A patent/EP1532228B1/de not_active Expired - Lifetime
Also Published As
Publication number | Publication date |
---|---|
AU2002368018B2 (en) | 2009-02-19 |
CA2489383C (en) | 2011-08-30 |
AU2002368018A1 (en) | 2003-12-31 |
EP1532228A1 (de) | 2005-05-25 |
EP1532228A4 (de) | 2006-08-16 |
CA2489383A1 (en) | 2003-12-24 |
ATE537241T1 (de) | 2011-12-15 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US11242298B2 (en) | Natural gas processing and systems | |
US8378162B2 (en) | Process for methane conversion | |
US7714180B2 (en) | Process and apparatus for recovering olefins | |
US7915461B2 (en) | Process for the conversion of natural gas to hydrocarbon liquids | |
US20150158789A1 (en) | Methods and Systems for Producing Liquid Hydrocarbons | |
WO1993013039A1 (en) | An olefins process which combines hydrocarbon cracking with methane coupling | |
CN111094220B (zh) | 使用二氧化碳对乙烷的氧化脱氢 | |
KR101026317B1 (ko) | 묽은 에틸렌 스트림들로부터 프로필렌 및 에틸벤젠 제조방법 | |
US6433235B1 (en) | Method for converting methane-containing gaseous hydrocarbon mixtures to liquid hydrocarbons | |
US10435338B2 (en) | Method and process for converting the ethylene present in the overhead effluent from a FCC in a manner such as to increase the propylene production | |
RU2563628C2 (ru) | Способ конверсии метана | |
EP1532228B1 (de) | Verfahren zur umwandlung von methanhaltigen gasförmigen kohlenwasserstoffgemischen in flüssige kohlenwasserstoffe | |
US11945762B2 (en) | Process for the conversion of light alkanes to aromatic compounds with improved selectivity | |
CA3077100C (en) | A process for converting a natural gas feedstock with inert content to chemical intermediates | |
NZ537236A (en) | Method for converting methane-containing gaseous hydrocarbon mixtures to liquid hydrocarbons | |
RU2540270C1 (ru) | Способ глубокой переработки нефтезаводского углеводородного газа | |
US3660272A (en) | Gasoline production from wellhead natural gas | |
NL2016236B1 (en) | Process and system for the production of olefins. | |
CN115710152A (zh) | 一种碳四综合利用的dcc一体化制备聚合级烯烃的系统和方法 | |
CA2931610C (en) | Methods and systems for producing liquid hydrocarbons | |
CN116801972A (zh) | 从来自精炼和石油化学生产过程的干燥烃气中回收轻烯烃用于生产烷基化物 |
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: 20041227 |
|
AK | Designated contracting states |
Kind code of ref document: A1 Designated state(s): AT BE CH CY DE DK ES FI FR GB GR IE IT LI LU MC NL PT SE TR |
|
AX | Request for extension of the european patent |
Extension state: AL LT LV MK RO SI |
|
DAX | Request for extension of the european patent (deleted) | ||
A4 | Supplementary search report drawn up and despatched |
Effective date: 20060719 |
|
RIC1 | Information provided on ipc code assigned before grant |
Ipc: C10G 67/02 20060101AFI20040106BHEP Ipc: C10G 57/00 20060101ALI20060713BHEP Ipc: C07C 4/02 20060101ALI20060713BHEP Ipc: C10G 51/06 20060101ALI20060713BHEP Ipc: C10G 29/20 20060101ALI20060713BHEP Ipc: C07C 2/58 20060101ALI20060713BHEP |
|
17Q | First examination report despatched |
Effective date: 20080702 |
|
GRAP | Despatch of communication of intention to grant a patent |
Free format text: ORIGINAL CODE: EPIDOSNIGR1 |
|
GRAS | Grant fee paid |
Free format text: ORIGINAL CODE: EPIDOSNIGR3 |
|
GRAA | (expected) grant |
Free format text: ORIGINAL CODE: 0009210 |
|
AK | Designated contracting states |
Kind code of ref document: B1 Designated state(s): AT BE CH CY DE DK ES FI FR GB GR IE IT LI LU MC NL PT SE TR |
|
REG | Reference to a national code |
Ref country code: GB Ref legal event code: FG4D |
|
REG | Reference to a national code |
Ref country code: CH Ref legal event code: EP |
|
REG | Reference to a national code |
Ref country code: IE Ref legal event code: FG4D |
|
REG | Reference to a national code |
Ref country code: DE Ref legal event code: R096 Ref document number: 60241770 Country of ref document: DE Effective date: 20120315 |
|
REG | Reference to a national code |
Ref country code: NL Ref legal event code: VDEP Effective date: 20111214 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: SE Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20111214 Ref country code: NL Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20111214 Ref country code: GR Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20120315 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: CY Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20111214 Ref country code: BE Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20111214 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: PT Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20120416 |
|
REG | Reference to a national code |
Ref country code: AT Ref legal event code: MK05 Ref document number: 537241 Country of ref document: AT Kind code of ref document: T Effective date: 20111214 |
|
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 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: DK Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20111214 |
|
26N | No opposition filed |
Effective date: 20120917 |
|
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 FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20111214 |
|
REG | Reference to a national code |
Ref country code: DE Ref legal event code: R097 Ref document number: 60241770 Country of ref document: DE Effective date: 20120917 |
|
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 FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20111214 Ref country code: MC Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20120630 |
|
REG | Reference to a national code |
Ref country code: CH Ref legal event code: PL |
|
REG | Reference to a national code |
Ref country code: CH Ref legal event code: PL |
|
GBPC | Gb: european patent ceased through non-payment of renewal fee |
Effective date: 20120614 |
|
REG | Reference to a national code |
Ref country code: IE Ref legal event code: MM4A |
|
REG | Reference to a national code |
Ref country code: FR Ref legal event code: ST Effective date: 20130228 |
|
REG | Reference to a national code |
Ref country code: DE Ref legal event code: R119 Ref document number: 60241770 Country of ref document: DE Effective date: 20130101 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: IE Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20120614 Ref country code: ES Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20120325 Ref country code: FR Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20120702 Ref country code: DE Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20130101 Ref country code: GB Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20120614 Ref country code: CH Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20120630 Ref country code: LI Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20120630 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: FI Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20111214 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: TR Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20111214 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: LU Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20120614 |