CN103998882A - Method and apparatus for removing nitrogen from a cryogenic hydrocarbon composition - Google Patents
Method and apparatus for removing nitrogen from a cryogenic hydrocarbon composition Download PDFInfo
- Publication number
- CN103998882A CN103998882A CN201280061150.2A CN201280061150A CN103998882A CN 103998882 A CN103998882 A CN 103998882A CN 201280061150 A CN201280061150 A CN 201280061150A CN 103998882 A CN103998882 A CN 103998882A
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- Prior art keywords
- nitrogen
- stripping
- liquid
- nitrogen stripping
- low temperature
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- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 title claims abstract description 466
- 229910052757 nitrogen Inorganic materials 0.000 title claims abstract description 234
- 150000002430 hydrocarbons Chemical class 0.000 title claims abstract description 166
- 229930195733 hydrocarbon Natural products 0.000 title claims abstract description 165
- 239000004215 Carbon black (E152) Substances 0.000 title claims abstract description 140
- 238000000034 method Methods 0.000 title claims abstract description 140
- 239000000203 mixture Substances 0.000 title claims abstract description 83
- 239000007788 liquid Substances 0.000 claims abstract description 161
- 230000008569 process Effects 0.000 claims abstract description 108
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 98
- 239000003507 refrigerant Substances 0.000 claims description 79
- 239000007789 gas Substances 0.000 claims description 34
- 239000012530 fluid Substances 0.000 claims description 33
- 238000001816 cooling Methods 0.000 claims description 20
- 238000009833 condensation Methods 0.000 claims description 18
- 230000005494 condensation Effects 0.000 claims description 18
- 230000005484 gravity Effects 0.000 claims description 14
- 238000000926 separation method Methods 0.000 claims description 14
- 239000002912 waste gas Substances 0.000 claims description 14
- 239000000446 fuel Substances 0.000 claims description 13
- 239000007791 liquid phase Substances 0.000 claims description 12
- 238000010992 reflux Methods 0.000 claims description 10
- 239000002737 fuel gas Substances 0.000 claims description 9
- 239000012071 phase Substances 0.000 claims description 7
- 235000013372 meat Nutrition 0.000 claims description 6
- 238000001704 evaporation Methods 0.000 claims description 4
- 230000008020 evaporation Effects 0.000 claims description 4
- 239000000284 extract Substances 0.000 claims description 4
- 238000000605 extraction Methods 0.000 claims description 3
- 230000015572 biosynthetic process Effects 0.000 claims description 2
- 238000002360 preparation method Methods 0.000 claims 1
- 238000011068 loading method Methods 0.000 description 18
- 239000003949 liquefied natural gas Substances 0.000 description 14
- 238000007710 freezing Methods 0.000 description 11
- 230000008014 freezing Effects 0.000 description 11
- 238000007906 compression Methods 0.000 description 9
- 238000010438 heat treatment Methods 0.000 description 8
- 239000003345 natural gas Substances 0.000 description 8
- 238000011144 upstream manufacturing Methods 0.000 description 8
- 230000008901 benefit Effects 0.000 description 7
- 238000011084 recovery Methods 0.000 description 7
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 6
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 description 6
- 230000006835 compression Effects 0.000 description 6
- 230000001105 regulatory effect Effects 0.000 description 6
- 230000006837 decompression Effects 0.000 description 5
- OFBQJSOFQDEBGM-UHFFFAOYSA-N n-pentane Natural products CCCCC OFBQJSOFQDEBGM-UHFFFAOYSA-N 0.000 description 5
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 description 4
- 238000013459 approach Methods 0.000 description 4
- 239000002826 coolant Substances 0.000 description 4
- 239000001569 carbon dioxide Substances 0.000 description 3
- 229910002092 carbon dioxide Inorganic materials 0.000 description 3
- 238000011026 diafiltration Methods 0.000 description 3
- 239000001294 propane Substances 0.000 description 3
- 238000009835 boiling Methods 0.000 description 2
- 230000005587 bubbling Effects 0.000 description 2
- 125000004122 cyclic group Chemical group 0.000 description 2
- 239000000945 filler Substances 0.000 description 2
- NNPPMTNAJDCUHE-UHFFFAOYSA-N isobutane Chemical compound CC(C)C NNPPMTNAJDCUHE-UHFFFAOYSA-N 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 238000002156 mixing Methods 0.000 description 2
- IJDNQMDRQITEOD-UHFFFAOYSA-N n-butane Chemical compound CCCC IJDNQMDRQITEOD-UHFFFAOYSA-N 0.000 description 2
- 238000005057 refrigeration Methods 0.000 description 2
- 230000003068 static effect Effects 0.000 description 2
- 230000007704 transition Effects 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- VGGSQFUCUMXWEO-UHFFFAOYSA-N Ethene Chemical compound C=C VGGSQFUCUMXWEO-UHFFFAOYSA-N 0.000 description 1
- 239000005864 Sulphur Substances 0.000 description 1
- 238000009825 accumulation Methods 0.000 description 1
- 230000002411 adverse Effects 0.000 description 1
- 150000004945 aromatic hydrocarbons Chemical class 0.000 description 1
- 239000001273 butane Substances 0.000 description 1
- 239000003245 coal Substances 0.000 description 1
- 238000002485 combustion reaction Methods 0.000 description 1
- 230000001276 controlling effect Effects 0.000 description 1
- 230000006378 damage Effects 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 230000002349 favourable effect Effects 0.000 description 1
- 238000007701 flash-distillation Methods 0.000 description 1
- 238000007667 floating Methods 0.000 description 1
- 238000002513 implantation Methods 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- 238000009413 insulation Methods 0.000 description 1
- 239000001282 iso-butane Substances 0.000 description 1
- 235000013847 iso-butane Nutrition 0.000 description 1
- 230000002045 lasting effect Effects 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- QJGQUHMNIGDVPM-UHFFFAOYSA-N nitrogen group Chemical group [N] QJGQUHMNIGDVPM-UHFFFAOYSA-N 0.000 description 1
- 239000007793 ph indicator Substances 0.000 description 1
- 238000004064 recycling Methods 0.000 description 1
- 238000004088 simulation Methods 0.000 description 1
- -1 sulphur compounds Chemical class 0.000 description 1
- 238000002207 thermal evaporation Methods 0.000 description 1
- 231100000331 toxic Toxicity 0.000 description 1
- 230000002588 toxic effect Effects 0.000 description 1
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J2200/00—Processes or apparatus using separation by rectification
- F25J2200/74—Refluxing the column with at least a part of the partially condensed overhead gas
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J2205/00—Processes or apparatus using other separation and/or other processing means
- F25J2205/02—Processes or apparatus using other separation and/or other processing means using simple phase separation in a vessel or drum
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J2210/00—Processes characterised by the type or other details of the feed stream
- F25J2210/06—Splitting of the feed stream, e.g. for treating or cooling in different ways
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J2230/00—Processes or apparatus involving steps for increasing the pressure of gaseous process streams
- F25J2230/60—Processes or apparatus involving steps for increasing the pressure of gaseous process streams the fluid being hydrocarbons or a mixture of hydrocarbons
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J2240/00—Processes or apparatus involving steps for expanding of process streams
- F25J2240/30—Dynamic liquid or hydraulic expansion with extraction of work, e.g. single phase or two-phase turbine
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J2245/00—Processes or apparatus involving steps for recycling of process streams
- F25J2245/02—Recycle of a stream in general, e.g. a by-pass stream
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J2245/00—Processes or apparatus involving steps for recycling of process streams
- F25J2245/90—Processes or apparatus involving steps for recycling of process streams the recycled stream being boil-off gas from storage
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J2280/00—Control of the process or apparatus
- F25J2280/02—Control in general, load changes, different modes ("runs"), measurements
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
- F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
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- Engineering & Computer Science (AREA)
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- Thermal Sciences (AREA)
- General Engineering & Computer Science (AREA)
- Chemical & Material Sciences (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Chemical Kinetics & Catalysis (AREA)
- General Chemical & Material Sciences (AREA)
- Separation By Low-Temperature Treatments (AREA)
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Abstract
Nitrogen is removed from a cryogenic hydrocarbon composition. The cryogenic hydrocarbon composition is split into a first portion and a second portion having the same composition and phase as the first portion. The first portion is fed to a nitrogen stripper column, operating at a stripping pressure, from which a nitrogenstripped liquid is drawn. The second portion is fed into the nitrogen-stripped liquid or in a liquid hydrocarbon product stream or in a process vapour which are produced from the nitrogen-stripped liquid involving at least a step of depressurizing the nitrogen-stripped liquid to a flash pressure that is lower than the stripping pressure. The second portion bypasses the nitrogen stripper column between the stream splitting and the feeding of the second portion into the nitrogen-stripped liquid or the liquid hydrocarbon product stream or the process vapour.
Description
Technical field
The present invention relates to a kind of for the method and apparatus from low temperature hydrocarbon compositions separation of nitrogen.
Background technology
Liquefied natural gas (LNG) forms the important example economically of this low temperature hydrocarbon compositions.Natural gas is available fuel source, and the source of various hydrocarbon compounds.Due to many reasons, conventionally wish at the source place of natural gas flow or approach the source of natural gas flow, liquefied natural gas in LNG plant.For example, than gas form, natural gas is easier to as fluid storage and in the interior conveying of long distance, because it occupies less volume, and without under high pressure storing.
WO 2011/009832 has described a kind of method of the heterogeneous hydrocarbon stream for the treatment of being produced by natural gas, wherein by more lower boiling component (as nitrogen) from as described in separate heterogeneous hydrocarbon stream, there is the more liquefied natural gas stream of this more lower boiling component of low content to produce.It utilizes two continuous gas/liquid separation devices that operate under different pressures.Heterogeneous hydro carbons is flow to material to the first gas/liquid separation device under the first pressure.The bottom of described the first gas/liquid separation device is spread and is handed to the second gas/liquid separation device, and described the second gas/liquid separation device provides the steam under the second pressure lower than under described the first pressure.Steam compresses in overhead stream compressor, and is back to described the first gas/liquid separation device as stripping steam flow.
A shortcoming of the method and apparatus described in WO 2011/009832 is to need two large gas/liquid separation devices.
Summary of the invention
The invention provides a kind of method of removing nitrogen from low temperature hydrocarbon compositions, described low temperature hydrocarbon compositions comprises the liquid phase containing nitrogen and methane, and described method comprises:
-the low temperature hydrocarbon compositions comprising containing the liquid phase of nitrogen and methane is provided;
-the first nitrogen stripping device incoming flow under stripping pressure is fed to nitrogen stripping tower, described nitrogen stripping tower comprises the inner stripping of at least one that be arranged in nitrogen stripping tower portion section, the Part I that described the first nitrogen stripping device incoming flow comprises low temperature hydrocarbon compositions;
-liquid from the liquid storage spatial extraction of the nitrogen stripping tower of described stripping portion section below through nitrogen stripping;
-prepare at least liquid hydrocarbon product stream and process steam by the described liquid through nitrogen stripping, at least comprise the step to the flashing pressure lower than described stripping pressure by the described liquid pressure-reducing through nitrogen stripping;
-described process steam is compressed to at least stripping pressure, obtain thus compressed vapour;
-stripping steam flow is passed in the nitrogen stripping tower at the level place below described stripping portion section gravity at least stripping part that described stripping steam flow comprises described compressed vapour;
-discharge is as the vapor fraction of waste gas, and described vapor fraction comprises the discharge cut available from the overhead vapor of the top section of described nitrogen stripping tower;
-described low temperature hydrocarbon compositions diverting flow is become to described Part I and has the composition identical with described Part I and the Part II of phase;
-described Part II is decompressed to described flashing pressure;
-described Part II is fed in following at least one: through liquid, liquid hydrocarbon product stream and the process steam of nitrogen stripping;
Wherein, from described diverting flow to described charging Part II, described Part II is walked around described nitrogen stripping tower.
On the other hand, the invention provides that a kind of described low temperature hydrocarbon compositions comprises the liquid phase containing nitrogen and methane for remove the device of nitrogen from low temperature hydrocarbon compositions, described device comprises:
-being connected to the low temperature feeding line in the source of low temperature hydrocarbon compositions, described low temperature hydrocarbon compositions comprises the liquid phase containing nitrogen and methane;
-nitrogen stripping the tower that is communicated with described low temperature feeding line fluid, described nitrogen stripping tower comprises the inner stripping of at least one that be arranged in nitrogen stripping tower portion section;
-overhead vapor discharge pipe line, described overhead vapor discharge pipe line is communicated with described nitrogen stripping tower via the headroom in described nitrogen stripping tower;
-through the discharge pipe line of the liquid of nitrogen stripping, the discharge pipe line of the described liquid through nitrogen stripping is communicated with the liquid storage space in nitrogen stripping tower below the gravity of described stripping portion section;
-intermediate relief device in the discharge pipe line of the described liquid through nitrogen stripping, described intermediate relief device fluid is connected to described nitrogen stripping tower, and arrange in order to receive from the liquid storage space of described nitrogen stripping tower through the liquid of nitrogen stripping and by the described liquid pressure-reducing through nitrogen stripping, described intermediate relief device is at the stripping that comprises described nitrogen stripping tower on the interface on the pressure side and between flashing pressure side;
-be arranged at the liquid hydrocarbon product pipeline in described flashing pressure side, flow to discharge the liquid hydrocarbon product being produced by the described liquid through nitrogen stripping;
-be arranged at the process steam pipeline in described flashing pressure side, to receive the process steam being produced by the described liquid through nitrogen stripping;
-be arranged at the process compressor in described process steam pipeline, it arranges in order to receive described process steam and to compress described process steam, provide compressed vapour with the process compressor discharge place at described process compressor, described process compressor is at stripping on the described interface on the pressure side and between flashing pressure side;
-stripping vapor line, the level place of described stripping vapor line below the gravity of described stripping portion section is communicated with described nitrogen stripping tower fluid, and arranges in order to receive at least stripping part from the described compressed vapour of described process compressor;
-initial flow current divider in described low temperature feeding line, the setting of described initial flow current divider is in order to be divided into Part I by described low temperature hydrocarbon compositions and to have the composition identical with described Part I and the Part II of phase;
The-the first feeding line, described the first feeding line is for being sent to described nitrogen stripping tower from the Part I of described initial flow current divider;
The-the second feeding line, described the second feeding line is for being sent to from the Part II of described initial flow current divider as lower at least one: through liquid line, liquid hydrocarbon product pipeline and the process steam pipeline of nitrogen stripping, described the second feeding line is walked around described nitrogen stripping tower.
Brief description of the drawings
Use embodiment and with reference to accompanying drawing, below further illustrating the present invention, in the accompanying drawings:
Fig. 1 schematically shows process chart, and it represents to introduce the method and apparatus of one embodiment of the invention; With
Fig. 2 schematically shows process chart, and it represents to introduce the method and apparatus of another embodiment of the present invention.
In these figure, identical Reference numeral will be used in reference to same or similar parts.In addition, single Reference numeral is by for determining pipeline or pipeline and the stream being transmitted by this pipeline.
Detailed description of the invention
This description relates to from comprise the low temperature hydrocarbon compositions containing the liquid phase of nitrogen and methane removes nitrogen.Low temperature hydrocarbon compositions is divided into Part I and has the composition identical with described Part I and the Part II of phase.Described Part I is fed to the nitrogen stripping tower operating under stripping pressure, extracts from described nitrogen stripping tower through the liquid of nitrogen stripping.Described Part II is fed in the liquid of nitrogen stripping or liquid hydrocarbon product stream in or in process steam, described liquid hydrocarbon product stream or process steam are made by the above-mentioned liquid through nitrogen stripping, and relate to major general the step to the flashing pressure lower than stripping pressure through the liquid pressure-reducing of nitrogen stripping.Stripping steam flow is passed to nitrogen stripping tower, at least stripping part that described stripping steam flow comprises process steam after compression.
Be fed in the liquid of nitrogen stripping and/or liquid hydrocarbon product stream and/or process steam at diverting flow and by Part II between, described Part II is walked around described nitrogen stripping tower.
Therefore, be fed to the situation of nitrogen stripping tower than the whole charging of low temperature hydrocarbon compositions, the liquid carrying capacity of nitrogen stripping tower reduces, and enough liquid can be held in nitrogen stripping tower simultaneously, to be conducive to use the effective stripping of stripping steam flow.Therefore,, than the situation (wherein the first gas/liquid separation device receives pending whole heterogeneous hydrocarbon stream) of WO2011/009832, the size of nitrogen stripping tower can be less.
Use the solution proposing at present, the amount that remains on the nitrogen in the liquid hydrocarbon product stream of generation can keep below the maximum nitrogen index of appointment, and is not that whole low temperature hydrocarbon compositions is through nitrogen stripping tower simultaneously.Liquid hydrocarbon product stream can store and carry under atmospheric pressure at its cryogenic temperature with approximately.
The solution proposing also produces the waste gas being made up of vapor fraction, and described vapor fraction comprises the discharge cut available from the overhead vapor of the top section of nitrogen stripping tower.Vapor fraction can contain the nitrogen of significant quantity, the nitrogen of possible 50mol% to 95mol%.But preferably, under the fuel gas pressure higher than stripping pressure not, described vapor fraction can still be used as fuel gas stream.
Preferably, waste gas is not consuming under the fuel gas pressure higher than stripping pressure.But, can avoid the needs of special fuel air compressor.In addition, by being chosen in the stripping pressure under the pressure that exceedes fuel gas pressure, any compression that is applied to process steam has extra associated benefits, for example, increase the enthalpy of process steam, and this allows process steam as stripped vapor.
It is suggested, when low temperature hydrocarbon compositions contains 1.5mol% (preferably 1.8mol%) until when the nitrogen of 5mol%, method and apparatus in this paper is the most favourable.When nitrogen content is during lower than about 1.8mol% and/or lower than about 1.5mol%, existing selectable method is also enough to work.
The method and apparatus proposing is suitable for especially in conjunction with hydro carbons liquefaction system (as natural gas liquefaction system) application, to remove nitrogen from the thick liquiefied product producing hydro carbons liquefaction system.Find, even when thick liquiefied product or low temperature hydrocarbon compositions contains 1mol% (or about 1mol%) until when the nitrogen of the quite high amount of 5mol% (or until about 5mol%), gained liquid hydrocarbon product can meet the nitrogen content in the index of the nitrogen between 0.5 to 1mol%.The remainder of nitrogen discharges together with the part of the vapor fraction in waste gas and the methane of controlled quatity.
Fig. 1 shows a kind of device that comprises one embodiment of the invention.Low temperature feeding line 8 is communicated with nitrogen stripping tower 20 fluids via the first entrance system 21.
Liquefaction system 100 can be arranged at the upstream of low temperature feeding line 8.Liquefaction system 100 is as the source of low temperature hydrocarbon compositions.Liquefaction system 100 is communicated with low temperature feeding line 8 fluids via main depressurized system 5, and described main depressurized system 5 is communicated with liquefaction system 100 via thick liquiefied product pipeline 1.In the illustrated embodiment, main depressurized system 5 is made up of dynamic cell (as decompressor turbine 6) and static cell (as joule Thomson valve 5), but other variants are possible.
The first feeding line 10 connects the first entrance system 21 of low temperature feeding line 8 and nitrogen stripping tower 20 via initial flow current divider 9, described initial flow current divider 9 is arranged between low temperature feeding line 8 and the first feeding line 10.
The second feeding line 11 at its upstream side is connected to initial current divider 9.Described the second feeding line 11 is walked around nitrogen stripping tower 20, as is described further below.Initial current divider 9 is configured to the low temperature hydrocarbon compositions that flows through low temperature feeding line 8 to be divided into the Part I that is sent to the first feeding line 10 and the Part II that is sent to the second feeding line 11.A benefit of the second feeding line 11 and initial current divider 9 is, less in the comparable following situation of size of nitrogen stripping tower 20: low temperature feeding line 8 is directly connected and diverterless with the first feeding line 10, make whole low temperature hydrocarbon compositions enter nitrogen stripping tower 20 via the first entrance system 21.
Bypass flow flow control valve 15 is arranged in the second feeding line 11.Bypass flow flow control valve function is connected to the flow governor FC being arranged in the first feeding line 10.The low temperature hydrocarbon compositions that flow governor FC is configured to flow through by control low temperature feeding line 8 is divided into the split ratio of the first and second parts, thereby the flow of the described Part I by the first feeding line 10 is remained under predeterminated target flow.
Nitrogen stripping tower 20 comprises the inside stripping portion section 24 being arranged in nitrogen stripping tower 20.Overhead vapor discharge pipe line 30 is communicated with nitrogen stripping tower 20 via the top section 26 in nitrogen stripping tower 20.Discharge pipe line 40 through the liquid of nitrogen stripping is communicated with nitrogen stripping tower 20 via the liquid storage space 28 in nitrogen stripping tower 20, and described liquid storage space 28 is below the gravity of stripping portion section 24.
Nitrogen stripping tower 20 can comprise vapor/liquid contact intensifier, separates and denitrogenation to improve component.Depend on the nitrogen amount in Tolerance and the low temperature feeding line 8 of the nitrogen in nitrogen stripping liquid, can conventionally altogether need the theoretical stage between 2 to 8.In a particular, need 4 theoretical stages.This contact intensifier can, with the form of tower tray and/or filler, provide with the form of structuring or destructuring filler.Vapor/liquid contacts the part of the inner stripping of suitably forming at least partly of intensifier portion section 24.
Intermediate relief device 45 is arranged in the discharge pipe line 40 of the liquid of nitrogen stripping, and fluid is connected to nitrogen stripping tower 20 thus.In intermediate relief device 45 functions, be attached to liquid-level controller LC, described liquid-level controller LC cooperates with the liquid storage space 28 of nitrogen stripping tower 20.
Intermediate relief device 45 is arranged on the interface of the stripping that comprises nitrogen stripping tower 20 on the pressure side and between flashing pressure side.Flashing pressure side comprises liquid hydrocarbon product pipeline 90 and process steam pipeline 60, described liquid hydrocarbon product pipeline 90 arranges the liquid hydrocarbon product being produced by the liquid 40 through nitrogen stripping in order to discharge and flows, and described process steam pipeline 60 arranges the process steam being produced by the liquid 40 through nitrogen stripping in order to receive.Via initial flow current divider 9 and second feeding line 11 of as above short discussion, low temperature feeding line 8 is connected to following at least one: through discharge pipe line 40, liquid hydrocarbon product pipeline 90 and the process steam pipeline 60 of the liquid of nitrogen stripping.Preferably, the second feeding line 11 without for any indirect heat exchanger of any process streams indirect heat exchange.
In the embodiment illustrated, flashing pressure side also comprises the low-temperature storage tank that is connected to liquid hydrocarbon product pipeline 90 210 for storing liquid hydrocarbon product stream, optional Volatile Gas supply line 230 and optional end flash separator 50.
If this end flash separator 50 (as the situation in the embodiment of Fig. 1) is provided, the second feeding line 11 is suitably fed to end flash separator 50.In addition, this end flash separator 50 can be configured to via intermediate relief device 45 with through the discharge pipe line 40 of the liquid of nitrogen stripping and is communicated with nitrogen stripping tower 20 fluids.End flash separator 50 can be connected to low-temperature storage tank 210 via liquid hydrocarbon product pipeline 90 subsequently.Cryogenic pump 95 can be present in liquid hydrocarbon product pipeline 90, to assist that liquid hydrocarbon product is delivered to low-temperature storage tank 210.
As shown in the embodiment of Fig. 1, process steam pipeline 60 can be connected to optional end flash separator 50 via flashed vapour pipeline 64 and flash vapor stream brake control valve 65, and is connected to low-temperature storage tank 210 via optional Volatile Gas supply line 230.Rear one advantage connecting is, its allow to process as the Volatile Gas from low-temperature storage tank 210 of the part of process steam at least partly.
Also process compressor 260 is disposed to stripping on the pressure side and flashing pressure side between interface on.Preferably, process compressor 260 is by Motor Drive.Process compressor 260 is arranged in process steam pipeline 60, with receiving course steam compression process steam.Compressed vapour discharge pipe line 70 exports 261 fluids with the process compressor discharge of process compressor 260 and is connected.Suitably, process compressor 260 is provided with Anti-surge Control and recycle cooler, when process compressor (does not show in the drawings) and uses described recycle cooler in the time recycling and in start-up course.
Stripping vapor line 71 is communicated with nitrogen stripping tower 20 fluids via the second entrance system 23, and described the second entrance system 23 is configured in the level place of the gravity below of stripping portion section 24, and preferably above liquid storage space 28.Stripping vapor line 71 is connected to compressed vapour discharge pipe line 70 via optional bypass diverter 79.Stripping cap relief valve 75 is arranged in stripping vapor line 71.
Optionally, outside stripping steam supply pipeline 74 is set to be communicated with the second entrance system 23 fluids of nitrogen stripping tower 20.In one embodiment, as shown in Figure 1, optional outside stripping steam supply pipeline 74 is connected to compressed vapour discharge pipe line 70.Outside stripping flow of vapor control valve 73 is arranged in optional outside stripping steam supply pipeline 74.In one embodiment, optional outside stripping steam supply pipeline 74 is suitably connected in liquefaction system 100 or the hydrocarbon steam pipeline of liquefaction system 100 upstreams.
Burner 220 arranges in order to receive at least fuel meat from the steam of top discharge pipeline 30.Burner can comprise multiple fuel elements, and/or it can comprise as lower one or more: for example stove, boiler, incinerator, dual-fuel diesel engine or their combination.Boiler and dual-fuel diesel engine can be attached to generator.
Vapor line 87 is optionally configured to receive at least steam recycle sections from the steam of top discharge pipeline 30.Vapor line 87 is walked around nitrogen stripping tower 20, and charging is got back to as lower at least one: liquid hydrocarbon product pipeline 90 and process steam pipeline 60.Steam recirculation flow brake control valve 88 is preferably disposed in vapor line 87.A benefit of the vapor line 87 proposing is, it allows optionally to increase the nitrogen content in liquid hydrocarbon product stream 90.If optional end flash separator 50 is set, vapor line 87 is suitably fed to end flash separator 50.
Optionally, nitrogen stripping tower 20, except comprising inner stripping portion section 24, also comprises inner rectifying portion section 22.Inside rectifying portion section 22 is arranged in nitrogen stripping tower 20, and gravity is higher than stripping portion section 24.The first entrance system 21 gravity are arranged between inner rectifying portion section 22 and inner stripping portion section 24.Top section 26 is formed by the space in the nitrogen stripping tower 20 above the gravity of rectifying portion section 22.
Optional inside rectifying portion section 22 can comprise the vapor/liquid contact intensifier that is similar to inner stripping portion section 24, separates and denitrogenation further to improve component.
Conventionally, nitrogen stripping tower 20 cooperates with condenser, to provide by the downward liquid flow of inner stripping portion's section 24 and/or optional inside rectifying portion section 22.For example, in Fig. 1, condenser is with the form setting of the evaporator overhead condenser 35 in nitrogen stripping tower 20 outsides, and in Fig. 2, condenser is with the form setting of integral inner evaporator overhead condenser 235, and the inner one of the top section 26 of described integral inner evaporator overhead condenser 235 in nitrogen stripping tower 20 configures.
This condenser can be advantageously used in condensation again from the compression process steam of compressed vapour discharge pipe line 70 at least partly.For example, in the embodiment of Fig. 1, evaporator overhead condenser 35 is arranged in overhead vapor discharge pipe line 30.In evaporator overhead condenser 35 inside, overhead vapor can flow 132 indirect heat exchange with auxiliary refrigerant and contact and process, and heat is passed to auxiliary refrigerant stream with certain cooling load from overhead vapor thus.Auxiliary refrigerant stream flow control valve 135 is arranged in auxiliary refrigerant pipeline 132.
Cooling load controller 34 can be set to control cooling load, described cooling load is heat is passed to auxiliary refrigerant stream speed from overhead vapor.Suitably, cooling load controller 34 is configured to control cooling load with respect to need to the responding waste gas heat pH indicator pH of heating power.In the embodiment illustrated, cooling load controller 34 presents with the form of pressure controller PC and auxiliary refrigerant stream flow control valve 135, in described pressure controller PC and auxiliary refrigerant stream flow control valve 135 functions, is coupled to each other.
Still with reference to Fig. 1, top separator 33 is arranged on the downstream of overhead vapor discharge pipe line 30.Overhead vapor discharge pipe line 30 is disposed in top separator 33.Top separator 33 arranges in order to separate any NC vapor fraction from any condensate fraction of overhead vapor.Vapor fraction discharge pipe line 80 arranges to discharge vapor fraction.
Suitably, burner 220 is arranged in the downstream of vapor fraction discharge pipe line 80, to receive at least fuel meat of the vapor fraction in vapor fraction discharge pipe line 80.Suitably, the structure of optional vapor line 87 comprises optional vapor fraction current divider 89, described vapor fraction current divider 89 can be arranged in vapor fraction pipeline 80, thereby allows the controlled fluid between vapor fraction pipeline 80 and vapor line 87 to be communicated with.
Cold recovery heat exchanger 85 can be arranged in vapor fraction discharge pipe line 80, with before vapor fraction 80 is fed to any burner by flowing with cold recovery cold that 86 heat exchanges keep that vapor fraction 80 had.
In one embodiment, cold recovery stream 86 can comprise the effluent of the hydrocarbon feed stream in the hydrocarbon feed pipeline 110 that is derived from liquefaction system 100, or can be made up of described effluent.Gained through cooling effluent can be for example with low temperature feeding line 8 in the combination of low temperature hydrocarbon compositions.Therefore the productivity ratio that, the cold recovery heat exchange in cold recovery heat exchanger 85 has supplemented low temperature hydrocarbon compositions.In another embodiment, cold recovery stream 86 can comprise in overhead vapor discharge pipe line 30 (preferably in the part of overhead vapor discharge pipe line 30, overhead vapor is passed to evaporator overhead condenser 35 from nitrogen stripping tower 20 by described part) overhead vapor, or can be formed by described overhead vapor.Reduce thus the required power from the auxiliary refrigerant stream 132 in evaporator overhead condenser 35.
Return-flow system is set and enters nitrogen stripping tower 20 with the level place of part 36 above rectifying portion section 22 that at least reflux that allows condensate fraction.In the embodiment of Fig. 1, return-flow system comprises condensate fraction discharge pipe line 37, optional reflux pump 38 and optional condensate fraction current divider 39, described condensate fraction discharge pipe line 37 fluids are connected to the bottom of top separator 33, and described optional reflux pump 38 is arranged in condensate fraction discharge pipe line 37.Optional condensate fraction current divider 39 is via backflow part pipeline 36 with reflux inlet system 25 and fluid is connected condensate fraction discharge pipe line 37 and nitrogen stripping tower 20, and fluid connects condensate fraction discharge pipe line 37 and optional liquid recirculation line 13.Optional liquid recirculation line 13 and liquid hydrocarbon product pipeline 90 fluid connections.Fluid connection means liquid recirculation line 13 and is connected to any suitable position, and at least a portion of liquid recycle sections can flow to liquid hydrocarbon product pipeline 90 from described position, and remains in liquid phase simultaneously.Therefore, liquid recirculation line 13 can for example be connected directly to following one or more: nitrogen stripping tower 20, low temperature feeding line 8, the first feeding line 10, the second feeding line 11, the discharge pipe line 40 through the liquid of nitrogen stripping, optional end flash separator 50 and liquid hydrocarbon product pipeline 90.Recycle valve 14 is disposed in optional liquid recirculation line 13.Optional Modelling of Flow with Recirculation valve 32 by the control of Modelling of Flow with Recirculation controller (not shown) function can preferably be arranged in backflow part pipeline 36.
Liquid recirculation line 13 is preferably via recirculation path and liquid hydrocarbon product pipeline 90 fluid connections, and described recirculation path is without rectifying portion section 22 (if setting).In this way, liquid recirculation line 13 assists to avoid too much liquid to be fed to rectifying portion section 22, and avoids recycled liquid through rectifying portion section 22.This is conducive to be avoided the balance in disturbance nitrogen stripping tower 20.
Optional bypass diverter 79 is communicated with overhead vapor discharge pipe line 30 fluids, if evaporator overhead condenser 35 is set, and the preferred upstream side at evaporator overhead condenser 35 of described overhead vapor discharge pipe line 30.Optional steam bypass line 76 can be arranged between optional bypass diverter 79 and overhead vapor discharge pipe line 30.Steam bypass control valve (BCV) 77 is preferably disposed in steam bypass line 76.A benefit of this steam bypass line 76 is, in the time sometimes there is excessive process steam, it can process together with waste gas in vapor fraction discharge pipe line 80, and can not upset the material balance in nitrogen stripping tower 20.Steam bypass line 76 suitably extends along bypass diverter 79 and the bypass path between the overhead vapor discharge pipe line 30 of the upstream side of evaporator overhead condenser 35.Bypass path is extended between bypass diverter 79 and overhead vapor discharge pipe line 30 and/or vapor fraction discharge pipe line 80.Bypass path is without the inside stripping portion section 24 in nitrogen stripping tower 20.By this mode, can avoid the inner stripping of non-stripping part process portion section 24, this helps avoid the balance in disturbance nitrogen stripping tower 20.
Liquefaction system 100 in this description is up to the present to the utmost schematically to be described.It can represent any suitable hydro carbons liquefaction system and/or process, particularly prepare any gas deliquescence process of liquefied natural gas, and the present invention is not limited to the concrete selection of liquefaction system.The example of suitable liquefaction system uses unitary system refrigerant cycle process (to be generally cold-producing medium-SMR process of single mixing, as be described in the PRICO in Gastech (Dubai) the K R Johnsen and the article " LNG Production on floating platforms " of P Christiansen that propose in 1998, but be likely also one-component cold-producing medium, for example, be also described in the BHP-cLNG process in the aforementioned article of Johnsen and Christiansen); Two refrigerant circulation processes (for example conventional propane-mixing-cold-producing medium process of being conventionally abbreviated as C3MR, as being for example described in United States Patent (USP) 4,404, in 008, or for example (an one example is described in United States Patent (USP) 6 to double-mixed refrigerant-DMR – process, in 658,891), or two cyclic processes that for example wherein each refrigerant circulation contains one-component cold-producing medium); Process with three or more the compressor bank based on for three or more kind of refrigeration cycle (an one example is described in United States Patent (USP) 7,114,351 in).
Other examples of suitable liquefaction system are described in: United States Patent (USP) 5,832,745 (Shell SMR), United States Patent (USP) 6,295,833, United States Patent (USP) 5,657,643 (both are the variant of Black and Veatch SMR), United States Patent (USP) 6,370,910 (Shell DMR).Another suitable example of DMR is so-called Axens LIQUEFIN process, in the people's such as P-Y Martin that the 22nd the World Gas Conference (2003) of Tokyo propose as being for example described in the article that is entitled as " LIQUEFIN:AN INNOVATIVE PROCESS TO REDUCE LNG COSTS ".Other three suitable cyclic processes comprise for example United States Patent (USP) 6, 962, 060, WO2008/020044, United States Patent (USP) 7, 127, 914, DE3521060A1, United States Patent (USP) 5, 669, 234 (commercial being called, is optimized cascade process), United States Patent (USP) 6, 253, 574 (the commercial fluid-mixing cascade processes that are called), United States Patent (USP) 6, 308, 531, U. S. application announces 2008/0141711, the people " Large capacity single train AP-X (TM) Hybrid LNG Process " such as Mark J.Roberts, Doha, QAT, Gastech, 2002 (13-16 days in October, 2002).Provide these to advise illustrating applicability widely of the present invention, and be not intended to for exclusive list exclusive and/or possibility.
Preferably but necessarily, form any compressor, particularly any coolant compressor of part of the hydro carbons liquefaction process in liquefaction system by one or more Motor Drive, and can't help any steam turbine and/or gas turbine Mechanical Driven.This compressor can be only by one or more Motor Drive.Be not that all examples as listed above use motor as coolant compressor driver.Be apparent that any driver that can use except motor replace motor with greatest benefit in the present invention.
An example (wherein liquefaction system 100 is based on for example C3MR or Shell DMR) is briefly shown in Fig. 2.It uses low temperature heat exchanger 180, it is the form of Wound-rotor type heat exchanger in this case, and described Wound-rotor type heat exchanger comprises bottom and top hydrocarbon products tube bank (being respectively 181 and 182), bottom and top LMR tube bank (being respectively 183 and 184) and HMR tube bank 185.
Bottom is connected thick liquiefied product pipeline 1 and hydrocarbon feed pipeline 110 with top hydrocarbon products tube bank 181 with 182 fluids.The pre-cooled heat exchanger 115 of at least one freezing hydro carbons can be arranged in the hydrocarbon feed pipeline 110 of upstream of low temperature heat exchanger 180.
The main refrigerant of mix refrigerant form provides in main refrigerant circuit 101.Main refrigerant circuit 101 comprises and is consumed refrigerant lines 150 and compressed refrigerant lines 120, describedly be consumed the main aspiration end that refrigerant lines 150 connects low temperature heat exchanger 180 shell-side 186 of low temperature heat exchanger 180 (in this case for) and main refrigerant compressor 160, described compressed refrigerant lines 120 connects main refrigerant compressor 160 exhaust outlets and MR separator 128.One or more heat exchangers are arranged in compressed refrigerant lines 120, comprise in the present embodiment at least one ambient heat exchanger 124 and the pre-cooled heat exchanger 125 of at least one freezing main refrigerant.MR separator 128 is restrained 183 fluids via light refrigerant fraction pipeline 121 with bottom LMR and is connected, and is connected with HMR tube bank via recasting cryogen fraction line 122.
The pre-cooled heat exchanger 125 of the pre-cooled heat exchanger 115 of described at least one freezing hydro carbons and described at least one freezing main refrigerant is by pre-cooled cold-producing medium freezing (respectively via pipeline 127 and 126).Identical pre-cooled cold-producing medium can be shared by identical pre-cooled refrigerant circulation.In addition, the pre-cooled heat exchanger 115 of described at least one freezing hydro carbons and the pre-cooled heat exchanger 125 of described at least one freezing main refrigerant capable of being combined become a pre-cooled heat exchanger unit (not shown).With reference to United States Patent (USP) 6,370,910 as nonrestrictive example.
Optional outside stripping steam supply pipeline 74 (if providing) can be suitably at the point in the downstream of the point of the upstream of the pre-cooled heat exchanger 115 of described at least one freezing hydro carbons, the pre-cooled heat exchanger 115 of described at least one freezing hydro carbons, or (for example possibly, if provide two or more freezing hydro carbons pre-cooled heat exchanger) some place between two continuous pre-cooled heat exchangers of freezing hydro carbons is connected to hydrocarbon feed pipeline 110, to obtain the part from the hydrocarbon feed stream of hydrocarbon feed pipeline 110.
Transition point place between top (182,184) and bottom (181,183) tube bank, HMR tube bank 185 is connected with HMR pipeline 141 fluids, in described HMR pipeline 141, configures HMR control valve 144.HMR pipeline 141 is communicated with shell-side 186 fluids of low temperature heat exchanger 180, and via shell-side 186 and with in bottom hydrocarbon products tube bank 181 and bottom LMR tube bank 183 and HMR tube bank 185 each heat exchange setting and be consumed refrigerant lines 150 fluids and be communicated with.
Above upper bundle 182 and 184, approach the top of low temperature heat exchanger 180, LMR tube bank 184 is connected with LMR pipeline 131 fluids.The one LMR return line 133 is set up fluid and is communicated with between LMR pipeline 131 and the shell-side 186 of low temperature heat exchanger 180.LMR control valve 134 is disposed in a LMR return line 133.The one LMR return line 133 via described shell-side 186 and with the heat exchange setting of each and HMR tube bank 185 in each and LMR tube bank 183 and 184 in upper and lower hydrocarbon products tube bank 182 and 181 be consumed refrigerant lines 150 fluids and be communicated with.
Fig. 2 has shown a possible source of auxiliary refrigerant.LMR pipeline 131 is divided into auxiliary refrigerant pipeline 132 and a LMR return line 133.The 2nd LMR return line 138 is connected with auxiliary coolant lines 132 fluids via evaporator overhead condenser (form that it can integral inner evaporator overhead condenser 235 is implemented) at its upstream end, and the 2nd LMR return line 138 described in downstream suitably via a HMR pipeline 141 final be consumed refrigerant lines 150 and be connected.
Similar around the pipeline shown in pipeline and Fig. 1 of nitrogen stripping tower 20 in Fig. 2, and statement no longer in detail.Optional pipeline (comprising optional liquid recirculation line 13, optional outside stripping steam supply pipeline 74, optional steam bypass line 76 and optional vapor line 87) can be provided, but for clear and do not reproduce in Fig. 2.
The embodiment of comparison diagram 2 and the embodiment of Fig. 1, it should be noted that a difference is the form enforcement with integral inner evaporator overhead condenser 235 known in the art of evaporator overhead condenser 35, top separator 33 and return-flow system.If needed, optional liquid recirculation line 13 also can provide in the situation of Fig. 2, for example, by the optional condensate fraction current divider 39 of partially liq earial drainage tower tray (not shown) form is set on gravity between integral inner evaporator overhead condenser 235 and rectifying portion section 22.
For operating as follows from comprising the apparatus and method of removing nitrogen containing the low temperature hydrocarbon compositions of the liquid phase of nitrogen and methane:
The low temperature hydrocarbon compositions 8 comprising containing the liquid phase of nitrogen and methane is provided, and described low temperature hydrocarbon compositions 8 is preferably under the initial pressure of 2 to 15 absolute pressure bar (bara) and preferably at the temperature lower than-130 DEG C.
Low temperature hydrocarbon compositions 8 can be available from natural gas or oil reservoir or coal bed.Select as one, low temperature hydrocarbon compositions 8 also can be originated available from another, comprises for example synthetic source, as Fischer-Tropsch process.Preferably, low temperature hydrocarbon compositions 8 comprises at least methane of 50mol%, more preferably the methane of 80mol% at least.
In typical embodiment, can be by making hydrocarbon feed stream 110 realize the temperature lower than-130 DEG C through liquefaction system 100.In this liquefaction system 100, the hydrocarbon feed of the charging steam that comprises hydrocarbon-containifirst stream 110 can be for example in low temperature heat exchanger 180 with main refrigerant flow heat exchange, the charging steam of liquefaction feed stream is to provide the thick fluidized flow in thick liquiefied product pipeline 1 thus.Required low temperature hydrocarbon compositions 8 can be subsequently available from thick fluidized flow 1.
Main refrigerant flow can produce by the main refrigerant in circulation main refrigerant circuit 101, and the cold-producing medium 150 being consumed is thus compressed in main refrigerant compressor 160, thereby forms compressed cold-producing medium 120 by the cold-producing medium 150 being consumed.Via the one or more heat exchangers that are arranged in compressed refrigerant lines 120, heat extraction in the compressed cold-producing medium of discharge from autonomous coolant compressor 160.The compressed cold-producing medium of this generating portion condensation, it is separated into light refrigerant fraction 121 and heavy refrigerant fraction 122 in MR separator 128, described light refrigerant fraction 121 is become to be grouped into by the steam of the compressed cold-producing medium of partial condensation, and described heavy refrigerant fraction 122 is made up of the liquid component of the compressed cold-producing medium of partial condensation.
Light refrigerant fraction 121 is continuously via bottom LMR bundle 183 and top LMR bundle 184 and through low temperature heat exchanger 180, and heavy refrigerant fraction 122 via HMR bundle 185 through low temperature heat exchangers 180 until transition point.When through other tube bank of these points, point other light and heavy refrigerant fraction is cooling by the light and heavy refrigerant fraction of evaporation again in shell-side 186 (thereby producing the cold-producing medium 150 being consumed), and this has completed circulation.Meanwhile, hydrocarbon feed stream 110 is continuously via bottom hydro carbons bundle 181 and top hydro carbons bundle 182 and through low temperature heat exchanger 180, and liquefied and excessively cold by the light and heavy refrigerant fraction of identical evaporation.
Depend on source, hydrocarbon feed stream 110 can contain the component of the difference amount except methane and nitrogen, comprises that one or more non-hydrocarbons components except water are (as CO
2, Hg, H
2s and other sulphur compounds); For example, with one or more hydro carbons heavier than methane (ethane, propane and butane especially, and the pentane of possible less amount and aromatic hydrocarbons).The hydro carbons that molecular weight is at least the molecular weight of propane can be described as C3+ hydro carbons herein, the hydro carbons that molecular weight is at least the molecular weight of ethane can be described as C2+ hydro carbons herein.
If needed, the 110 pretreatment of hydrocarbon feed stream are to reduce and/or to remove one or more undesirable components, as CO
2and H
2s, or experienced other steps, as precharge etc.This step is well known to a person skilled in the art, and their mechanism is not further being discussed herein.Therefore, the composition of hydrocarbon feed stream 110 depends on the type of gas and position and applied one or more pretreatment and changes.
Thick fluidized flow 1 can be included in the nitrogen between the 1mol% to 5mol% under the liquefaction pressure under the original temperature between-165 DEG C to-120 DEG C and between common 15bara to 120bara.In many cases, original temperature can be between-155 DEG C to-140 DEG C.In described narrower range, cooling load required in liquefaction system 100 is lower than cooling load required under lower temperature, and under the pressure higher than 15bara cross cold enough height to avoid being decompressed to the excessive generation of the flashed vapour between 1 to 2bara.
Can be by thick fluidized flow 1 is mainly decompressed to initial pressure by liquefaction pressure, and obtain low temperature hydrocarbon compositions 8 by thick fluidized flow 1.In the time that low temperature hydrocarbon compositions 8 arrives initial flow current divider 9, low temperature hydrocarbon compositions 8 is divided into Part I and Part II in initial flow current divider 9, described Part I is the form of the first nitrogen stripping device incoming flow in the first feeding line 10, and described Part II is the form of the bypass incoming flow in the second feeding line 11.Described Part II has the composition identical with described Part I and phase.
The first nitrogen stripping device incoming flow 10 derived from low temperature hydrocarbon compositions 8 is fed to the nitrogen stripping tower 20 under stripping pressure via the first entrance system 21.
Stripping pressure is generally equal to or lower than initial pressure.In preferred embodiments, stripping pressure selection is between 2 to 15 absolute pressure bar.Preferably, stripping pressure is 4bara at least, because use slightly higher stripping pressure, the stripping steam in stripping vapor line 71 can be benefited from some the other enthalpys (form of the heat of compression) that are added into process streams 60 in process compressor 260.Preferably, stripping pressure is 8bara at the most, to be conducive to the separative efficiency in nitrogen stripping tower 20.In addition,, if in the scope of stripping pressure between 4 to 8bara, the waste gas in vapor fraction pipeline 80 can be easy to as so-called low-pressure fuel gas stream without further compression.
In one embodiment, the original temperature of thick fluidized flow 1 is-161 DEG C, and liquefaction pressure is 55bara.Main decompression can complete in two stages: first use the movement segment of expansion turbine 6, so that pressure is reduced to about 10bara from 55bara, then use Joule Thomson valve 7 in process segment, to be further decompressed to the pressure of 7bara.In this case, stripping pressure is assumed to be 6bara.
Overhead vapor stream 30 top sections 26 available from nitrogen stripping tower 20.Available from the vapor fraction 80 of overhead vapor stream 30 the discharge cut that comprises overhead vapor 30 as toxic emission.Suitably, at least fuel meat of vapor fraction 80 is passed to not higher than the burner 220 under the fuel gas pressure of stripping pressure.
Extract the liquid 40 through nitrogen stripping from the liquid storage space 26 of nitrogen stripping tower 20.Temperature through the temperature of the liquid 40 of nitrogen stripping usually above the first nitrogen stripping device incoming flow 10.Conventionally, expection is the temperature higher than the first nitrogen stripping device incoming flow 10 through the temperature of the liquid 40 of nitrogen stripping, and is between-140 DEG C to-80 DEG C, is preferably between-140 DEG C to-120 DEG C.
Then preferably use intermediate relief device 45 that the liquid through nitrogen stripping 40 is decompressed to flashing pressure, described flashing pressure is lower than stripping pressure, and suitably in the scope between 1 to 2 absolute pressure bar.Preferably, in the scope of flashing pressure between 1.0 to 1.4bara.Under the difference between slightly higher flashing pressure and stripping pressure, the stripping steam in stripping vapor line 71 can be benefited from some other heats of compression that are added into process streams 60 in process compressor 260.
Intermediate relief device 45 can be controlled by liquid-level controller LC, described liquid-level controller LC is set as: if more than in the liquid storage space 26 of nitrogen stripping tower 20, the fluid level of accumulation is increased to target level, described liquid-level controller LC increases by the flow of intermediate relief device.As the result of decompression, temperature is reduced to below-160 DEG C conventionally.The liquid hydrocarbon product stream 90 making thus can keep under atmospheric pressure conventionally in the low-temperature storage tank of open insulation.
Also production process steam 60.Process steam 60 can comprise the flashed vapour 64 being produced by the decompression of the liquid 40 through nitrogen stripping and/or the decompression of bypass incoming flow 11.
The Part II of the low temperature hydrocarbon compositions 8 of bypass incoming flow 11 forms for example can be passed to optional end flash separator 50 and enter in end flash separator 50.Low temperature hydrocarbon compositions 8 diverting flows become the first and second parts, make Part II 11 have the composition identical with Part I 10 and phase.
Can use bypass flow flow control valve 15 to control split ratio, described split ratio is defined as the flow with respect to the Part II of the flow of the low temperature hydrocarbon compositions in low temperature hydrocarbon compositions pipeline 8.Described bypass flow flow control valve 15 can be controlled by flow governor FC, to keep the first nitrogen stripping device incoming flow 10 to enter the predeterminated target flow in nitrogen stripping tower 20.If there is the superfluous flow that exceedes target flow, flow governor FC will increase the part of opening of bypass flow flow control valve 15, if there is underfed than target flow, flow governor FC will reduce to open part.
As general principle, split ratio can advantageously be chosen as between 50% to 95%.For nitrogen content higher in low temperature hydrocarbon compositions, conventionally recommend lower value, and for lower nitrogen content, preferably higher value.In one embodiment, the nitrogen content in low temperature hydrocarbon compositions 8 is 3.0mol%, and selected split ratio is 75% thus.
Subsequently the Part II that is derived from initial flow current divider 9 being fed at least one in discharge pipe line 40, liquid hydrocarbon product pipeline 90 and the process steam pipeline 60 of the liquid of nitrogen stripping, and before walking around nitrogen stripping tower 20, also described Part II is decompressed to described flashing pressure simultaneously.Suitably, optional Part II is passed in optional end flash separator 50.But, by initial flow current divider 9 to any one way of described charging subsequently, be derived from the Part II of initial flow current divider 9 preferably without undergoing any functional indirect heat exchange.In this context, term " functional indirect heat exchange " is intended to get rid of Part II in the second feeding line 11 and around intrinsic " non-functional " heat exchange and/or inappreciable heat exchange between the environment of the second feeding line 11.
Volatile Gas 230 conventionally comes from heat is added into liquid hydrocarbon product stream 90, and a part for liquid hydrocarbon product stream 90 is evaporated and formation Volatile Gas thus.In typical LNG factory, the generation of Volatile Gas can exceed the flow several times of flashed vapour, particularly in the process with so-called loading pattern operation engineering, therefore, if Shortcomings need to be contained in whole methane in Volatile Gas to use to the scene of heating power, important advantageously not only condensation flashed vapour, also condensation Volatile Gas more again.
In order to promote Volatile Gas to be passed to process steam stream 60, preferably, optional Volatile Gas supply line 230 connects vapor space and the process steam pipeline 60 in low temperature storage pipe 210.In order to promote flashed vapour 64 to be passed to process vapor stream 60, and further liquid hydrocarbon product stream 90 is denitrogenated, preferably, after the liquid pressure-reducing of nitrogen stripping, to be fed to through the liquid of nitrogen stripping in optional end flash separator, in described optional end flash separator, under flash separation pressure, be separated into liquid hydrocarbon product stream 90 and flashed vapour 64 through the liquid of nitrogen stripping.Flash separation pressure is equal to or less than flashing pressure, and suitably in the scope between 1 to 2 absolute pressure bar.In one embodiment, flash separation pressure is contemplated to 1.05bara.
Process steam 60 is compressed to at least stripping pressure, obtains thus compressed steam stream 70.Stripping steam flow 71 flows 70 available from compressed steam, and is passed to nitrogen stripping tower 20 via the second entrance system 23.Described stripping steam can be to contact adverse current with downward diafiltration by the liquid of stripping portion section 23 upwards diafiltration by stripping portion section 23.
If outside stripping steam supply pipeline 74 is communicated with setting with the second entrance system 23 fluids, outside stripping steam is optionally fed to nitrogen stripping tower 20 via the second entrance system 23.Can avoid thus the main destruction of nitrogen stripping tower 20, for example, not play in the situation of the effect that the compressed steam of q.s stream 70 is provided at process compressor 260.
Can relate to compressed steam stream 70 is divided into stripping steam flow 71 and steam by-passing part by compressed steam stream 70 acquisition stripping steam flows 71, described steam by-passing part does not comprise stripping part, and optionally injects overhead vapor pipeline 30 to walk around thus nitrogen stripping tower 20.Useful steam bypass control valve (BCV) 77 is controlled Selective implantation.Suitably, steam bypass control valve (BCV) 77 is by the pressure controller control on compressed vapour pipeline 70, and described pressure controller is set to respond the pressure increasing in compressed steam pipeline 70 and increases the part of opening of steam bypass control valve (BCV) 77.Expection allows to flow through steam bypass line 76 and to enter the flow of the steam by-passing part in overhead vapor stream 30 high especially in so-called loading pattern process, and the amount of the Volatile Gas in the time of described loading pattern is conventionally than much higher in so-called Holdover mode process.Preferably, steam bypass control valve (BCV) 77 cuts out completely in course of normal operation under Holdover mode.
In preferred embodiments, the intermediate flow of partial condensation is formed by overhead vapor 30.This relates to makes overhead vapor 30 and auxiliary refrigerant flow 132 indirect heat exchange, and heat is passed to auxiliary refrigerant stream 132 to select cooling load from overhead vapor 30 thus.The intermediate flow of gained partial condensation comprises condensate fraction and vapor fraction.
In the context of the present specification, cooling load has reflected the speed that heat exchanges in condenser, and it can for example, represent with power unit (watt or megawatt).Cooling load is to stand flow with the auxiliary refrigerant of the heat exchange of overhead vapor relevant.
Auxiliary refrigerant 132 flows under standard conditions and at the temperature of the bubbling point lower than overhead vapor stream 30, under standard conditions, preferably to have bubbling point (ISO13443 standard: under 1.0 atmospheric pressure 15 DEG C).This be conducive to condensation more relatively more a large amount be present in the methane in overhead vapor stream 30, thereby and then promote the controllability of the methane content in vapor fraction 80.For example, auxiliary refrigerant can contain the nitrogen between 5mol% to 75mol%.In a preferred embodiment, auxiliary refrigerant stream is formed by the slip-stream of main refrigerant flow, is more preferably formed by the slip-stream of light refrigerant fraction.A rear situation is shown in Fig. 2, but also applicable to the embodiment of Fig. 1.This slip-stream can be transmitted back in main refrigerant circuit expediently via the shell-side of low temperature heat exchanger 180 186, and wherein said slip-stream can still assist to extract heat in the stream from top and/or lower bundle.
In one embodiment, auxiliary refrigerant contemplated composition contains methane between nitrogen, the 30mol% to 60mol% between 25mol% to 40mol% and the C of 30mol% at the most
2(ethane and/or ethene), thus, auxiliary refrigerant contains these compositions of at least 95% and/or nitrogen and methane and is total up at least 65mol%.If use mix refrigerant for liquefying the excessively cold of hydrocarbon stream, the composition within the scope of these can be easy to derive from main refrigerant circuit.
Also may use kind of refrigeration cycle separately with the object for partial condensation overhead vapor stream 30.But, use and have the following advantages from the slip-stream tool of main refrigerant flow: the amount minimum of the other equipment of installation.For example, do not need other auxiliary refrigerant compressor and auxiliary refrigerant condenser.
Condensate fraction separates with vapor fraction under separating pressure in top separator 33, and described separating pressure can be lower than stripping pressure, and preferably in the scope between 2 to 15 absolute pressures bar.Vapor fraction is discharged via vapor fraction discharge pipe line 80.Condensate fraction is for example disposed to return-flow system from top separator 33 via condensate fraction discharge pipe line 37.
Therefore, evaporator overhead condenser 35 allows by any this steam is added into (compression) process vapor stream containing the stream of methane, thereby before condensation, form the steam methane of the part of thick liquiefied product 1 again, until exceed the degree of the aim parameter of the methane in discharge vapor fraction 80.Once the part of forming process steam 60 or compression process steam 70, steam methane can be managed and auxiliary refrigerant 132 heat exchanges, thus, from the overhead vapor from nitrogen stripping tower 20, condense steam methane selectively, and allow the major part of nitrogen to discharge together with waste gas simultaneously.Therefore, likely from low temperature hydrocarbon compositions 8, remove enough nitrogen, to be created in the liquid hydrocarbon product stream 90 in the required Maximum Index of nitrogen content, and in waste gas, do not produce than required more thermal capacity simultaneously.
Due to many reasons, before can being formed on, form the steam methane of the part of thick liquiefied product 1.In the course of normal operation of natural gas liquefaction facility, formed by (slightly) liquiefied product with following form containing the steam of methane:
-flashed vapour, it obtains the flash distillation of thick liquiefied product in comfortable decompression process; And
-Volatile Gas, it must be freed from the thermal evaporation that is added into the heat of liquiefied product and cause, and described heat is for example for entering storage tank, the ducted heat leak of LNG, and the form of inputting from the heat of the LNG of factory pump.In described operator scheme (being called Holdover mode operation) process, storage tank is filled by Liquefied Hydrocarbon series products in the time that Liquefied Hydrocarbon series products leaves equipment, and does not carry out any conveyor load operation simultaneously.When in Holdover mode, produce at the equipment side of storage tank containing the steam of methane.
The operator scheme of the LNG equipment in the time there is lasting conveyor load operation (ship loading operation conventionally) is called loading pattern operation.In loading pattern operating process, for example due to boats and ships tank initially cooling, by connecting storage tank and the pipeline of boats and ships and the heat leak of container, and from the heat input of LNG loading pump, Volatile Gas produces in addition in the boats and ships side of storage tank.
The solution proposing can be processed these steams in Holdover mode and loading pattern operating process.It has combined the condensation again of removing nitrogen and excessive steam methane from low temperature hydrocarbon compositions 8.In the situation of a small amount of factory of needs fuel (if use is from the situation of the electric drive factory of the electric power of external electrical network), this has formed good solution.
Suitably regulate the calorific value of the vapor fraction 80 being discharged by regulating the cooling load in evaporator overhead condenser 35.This can complete by cooling load controller 34.By regulating heat to be passed to the cooling load that auxiliary refrigerant flows, the relative quantity of methane in adjustable waste gas from overhead vapor.As a result of, the calorific value of adjustable discharge vapor fraction with heating power specifically need mate.This makes waste gas be suitable as fuel gas stream, even in the variable situation of the needs of calorific value.
When vapor fraction 80 as delivery of fuel to burner 220, and while being consumed by burner 220, adjustable calorific value, to mate with the actual needs of the heating power of burner 220.
Can select regulated calorific value as the suitable situation of the desired use of fuel gas according to waste gas.Can be according to DIN51857 standard calorific value.For many application, the calorific value regulating can with low heat value (LHV; Be sometimes referred to as net heating value) proportional, described low heat value may be defined as by burning specified amount (at first at 25 DEG C) and makes the temperature of combustion product be back to 150 DEG C of heats that discharge.This hypothesis does not reclaim the evaporation of water latent heat in product.
But, in order to regulate the object of calorific value in context of the present disclosure, without the actual calorific value of determining the vapor fraction being discharged on absolute value basis.Conventionally,, in order to make any shortage of sent heating power or excessively to reach minimum, regulate calorific value enough with respect to the actual needs of heating power.
Preferably, respond therefore relevant to regulated calorific value signal and automatically regulate cooling load.Therein vapor fraction is passed in selectivity consume person's (example burner 220 as shown in Figure 1) the embodiment of one or more methane, can respond required heating power and complete control, the partial discharge of controlling thus methane mates to obtain the calorific value needing.Suitably, auxiliary refrigerant stream flow control valve 135 can be controlled by pressure controller PC, to keep auxiliary refrigerant stream 132 by the predeterminated target flow of evaporator overhead condenser 35.Actual pressure in vapor fraction discharge pipe line 80 is therefore relevant to regulated calorific value.In the time that pressure drop is below horizontal to predeterminated target (it represents that the depletion rate of methane is higher than the delivery rate of vapor fraction 80), pressure controller PC is set as reducing the part of opening of auxiliary refrigerant stream flow control valve 135.On the contrary, in the time that pressure exceedes predeterminated target level, pressure controller PC is set as increasing the part of opening of auxiliary refrigerant stream flow control valve 135.
Expection vapor fraction 80 contains the nitrogen between 50mol% to 95mol%, the preferably nitrogen between 70mol% to 95mol% or the nitrogen between 50mol% to 90mol%, more preferably the nitrogen between 70mol% to 90mol%, the also more preferably nitrogen between 75mol% to 95mol%, the most preferably nitrogen between 75mol% to 90mol%.Expection condensate fraction 37 contains the nitrogen that is less than 35mol%.
If nitrogen stripping tower 20 is equipped with optional inside rectifying portion section 22 as above, the top section of the preferred nitrogen stripping tower 20 available from rectifying portion section 22 tops of overhead vapor stream 30.Originate in the level place above rectifying portion section 22, make at least backflow part 36 of condensate fraction enter nitrogen stripping tower 20.In the situation of the embodiment of Fig. 1, condensate fraction can be through optional reflux pump 38 (and/or its can in the current downflow that affects of gravity).Reflux part subsequently available from condensate fraction, and pack nitrogen stripping tower 20 into via reflux inlet system 25 and backflow part pipeline 36.In the situation of the embodiment of Fig. 2, condensate fraction separates in the inside of the top section of nitrogen stripping tower 20, and therefore above rectifying portion section, obtains, with upwards rise by the steam of rectifying portion section 22 contact and downward diafiltration by rectifying portion section 22.
The part that refluxes can contain whole condensate fraction, but optionally, condensate fraction is divided into liquid recycle sections and backflow part in the optional condensate fraction current divider 39 arranging, described liquid recycle sections is disposed in for example the first incoming flow 10 via liquid recirculation line 13, and described backflow part is disposed in nitrogen stripping tower 20 via reflux inlet system 25 and backflow part pipeline 36.The ability that condensate fraction is divided into backflow part 36 and liquid recycle sections 13 is conducive to make any excessive condensate fraction to turn to around rectifying portion section 22, for example, not disturb the operation of rectifying portion section 22.Can suitably control recycle valve 14 with the liquid-level controller that is arranged at the flow governor in condensate fraction discharge pipe line 37 and/or be arranged on top separator 33.
Partial condensation also can relate to the direct and/or indirect heat exchange with other streams in other continuous top heat exchangers that arrange.For example, cold recovery heat exchanger 85 can be a kind of top heat exchanger, and by described top heat exchanger, the partial condensation of overhead stream also comprises and vapor fraction 80 indirect heat exchange.
Can suitably optionally use optional vapor line 87 by optionally opening steam recirculation control valve 88, to increase the nitrogen amount being held in liquid hydrocarbon product stream 90.This can be by completing as follows: from vapor fraction, extract steam recycle sections, steam recycle sections is decompressed to flashing pressure, and subsequently steam recycle sections is injected to the liquid 40 through nitrogen stripping.The remainder that is not passed to the vapor fraction 80 in vapor line 87 can form fuel meat, and described fuel meat can be sent to burner 220.
In some embodiments, the aim parameter that is dissolved in the nitrogen in liquid hydrocarbon product stream 90 is between 0.5 to 1mol%, preferably approaches 1.0mol%, but is no more than as far as possible 1.1mol%.Steam recirculation flow brake control valve 88 regulates charging to be back in end flash separator 50 for example and walks around the amount of the vapor fraction stream 80 of nitrogen stripping tower 20 simultaneously.Therefore, can affect the nitrogen amount in liquid hydrocarbon product stream 90.In order further to contribute to meet target nitrogen content, can respond from being optionally arranged at the signal of the mass measurer QMI in liquid hydrocarbon product pipeline 90 and control steam recirculation flow brake control valve 88.
For Holdover mode (table 1) and loading pattern (table 2) both, carry out static simulation in the embodiment shown in Fig. 1.Supposing that low temperature hydrocarbon compositions 8 comprises exceedes the nitrogen of 90mol% and the mixture of methane (98.204mol%).In an embodiment, the amount of nitrogen (1.654mol%) and methane (98.204mol%) exceedes 99.8mol%, and the surplus of 0.142mol% is made up of carbon dioxide (0.005mol%).Carbon dioxide leaves described process via the liquid 40 through nitrogen stripping and liquid hydrocarbon product stream 90.In two kinds of situations, the split ratio of initial steam current divider 9 is approximately 75%.
Can find out, in Holdover mode and loading pattern, although the measurer of process steam has large difference, but the amount of the methane of discharge in vapor fraction 80 can be maintained at about under 80mol% and suitably in the scope between 10mol% to 25mol%, and the nitrogen content in liquid hydrocarbon product stream 90 remains in the target that approaches 1.0mol% and be no more than 1.1mol% simultaneously.
In Holdover mode, the Volatile Gas being made up of the nitrogen of about 17mol% and the methane of 83mol% of about 2.0kg/s is added into process via Volatile Gas supply line 230, and is about 4.4kg/s in Volatile Gas described in loading pattern.
In Holdover mode, steam is not guided through to steam bypass line 76, and in loading pattern, 30% in compressed vapour 70 is guided through to steam bypass line 76, to hold the other steam being brought by other Volatile Gas inflow.In loading pattern, liquid recirculation 13 is also increased to approximately 41% of described condensate fraction by approximately 8% of the condensate fraction in condensate fraction discharge pipe line 37.Flowing of other condensate fraction caused by the other methane of condensation again.
Liquefaction system 100 in calculating uses setting as shown in Figure 2, and the mix refrigerant in compressed refrigerant pipeline 120 has as being labeled as composition listed in the row of " 120 " in table 3.
Table 3: mix refrigerant composition (in mol%)
In Holdover mode, the pressure in compressed refrigerant pipeline 120 is 58bara, higher at pressure described in loading pattern, is 61bara.In two kinds of situations, the total pressure drop in bottom and the top LMR tube bank (being respectively 183 and 184) of low temperature heat exchanger is 13bar.The pressure drop being applied by auxiliary refrigerant stream flow control valve 135 for 39bar, is 42bar in Holdover mode situation in loading pattern, thereby for Holdover mode and loading pattern, the shell in the shell-side 186 of low temperature heat exchanger 180 is pressed identical.
The relative discharge of auxiliary refrigerant stream 132 is 11% of total LMR flow in LMR pipeline 131.In loading pattern, the relative discharge of auxiliary refrigerant stream 132 is 18% of total LMR flow in LMR pipeline 131.And actual flow is 1.6 times in Holdover mode situation, but than in Holdover mode operation, in loading pattern operation, make MR separator 128 in slightly more preference HMR of separation between HMR and LMR.
In as above embodiment, suppose that low temperature hydrocarbon compositions is containing the hydro carbons (C heavier than methane
2+ hydro carbons), for example following situation: low temperature hydrocarbon compositions is derived from non-conventional gas body source, as coalbed methane, shale gas or some possible synthetic source.But the method and apparatus proposing also can be applicable to wherein low temperature hydrocarbon compositions and contains the C of about 15mol% at the most
2the situation of+hydro carbons (comprising one or more that are selected from ethane, propane, iso-butane, normal butane and pentane).In fact, do not expect the C that these are other
2+ hydro carbons changes the running of the method and apparatus proposing, because it is expected that this C
2+ hydro carbons is all present in the waste gas of overhead vapor 30 or vapor fraction discharge pipe line 80 unlike the carbon dioxide of embodiment.
It will be apparent to those skilled in the art that the scope in the case of not departing from appended claims, can carry out the present invention in many different modes.
Claims (15)
1. from low temperature hydrocarbon compositions, remove the method for nitrogen, described low temperature hydrocarbon compositions comprises the liquid phase containing nitrogen and methane, and described method comprises:
-the low temperature hydrocarbon compositions comprising containing the liquid phase of nitrogen and methane is provided;
-the first nitrogen stripping device incoming flow under stripping pressure is fed to nitrogen stripping tower, described nitrogen stripping tower comprises the inner stripping of at least one that be arranged in nitrogen stripping tower portion section, the Part I that described the first nitrogen stripping device incoming flow comprises low temperature hydrocarbon compositions;
-liquid from the liquid storage spatial extraction of the nitrogen stripping tower of described stripping portion section below through nitrogen stripping;
-prepare at least liquid hydrocarbon product stream and process steam by the described liquid through nitrogen stripping, at least comprise the step to the flashing pressure lower than described stripping pressure by the described liquid pressure-reducing through nitrogen stripping;
-described process steam is compressed to at least stripping pressure, obtain thus compressed vapour;
-stripping steam flow is passed in the nitrogen stripping tower at the level place below described stripping portion section gravity at least stripping part that described stripping steam flow comprises described compressed vapour;
-discharge is as the vapor fraction of waste gas, and described vapor fraction comprises the discharge cut available from the overhead vapor of the top section of described nitrogen stripping tower;
-described low temperature hydrocarbon compositions diverting flow is become to described Part I and has the composition identical with described Part I and the Part II of phase;
-described Part II is decompressed to described flashing pressure;
-described Part II is fed to at least one in the liquid of nitrogen stripping, liquid hydrocarbon product stream and process steam;
Wherein, from described diverting flow to described charging Part II, described Part II is walked around described nitrogen stripping tower.
2. method according to claim 1, it also comprises:
-control described low temperature hydrocarbon compositions and be split into the split ratio of described Part I and described Part II, thus the flow of described Part I is remained under predeterminated target flow, described split ratio is defined as the flow with respect to the described Part I of described the first and second parts total flow together.
3. according to method in any one of the preceding claims wherein, in the scope of wherein said stripping pressure between 2 to 15 absolute pressures bar and/or wherein said flashing pressure be between 1 to 2 absolute pressure bar.
4. according to method in any one of the preceding claims wherein, it also comprises at least fuel meat of described vapor fraction is passed to not higher than the burner under the fuel gas pressure of stripping pressure.
5. according to method in any one of the preceding claims wherein, wherein said process steam comprises by heat being added into described liquid hydrocarbon product and flows the Volatile Gas obtaining, thus the part evaporation of liquid hydrocarbon product stream and form described Volatile Gas.
6. according to method in any one of the preceding claims wherein, wherein described, the described liquid pressure-reducing through nitrogen stripping is produced to flashed vapour to the process of described flashing pressure, and wherein said process steam comprises described flashed vapour.
7. method according to claim 6, wherein by described in the preparation of the described liquid through nitrogen stripping at least liquid hydrocarbon product stream and process steam also comprise the steps: be equal to or less than under the flash separation pressure of flashing pressure, the described liquid through nitrogen stripping is separated into liquid hydrocarbon product in the flash separator of end and flows and flashed vapour.
8. method according to claim 7, wherein said described Part II be fed to at least one in liquid, liquid hydrocarbon product stream and the process steam of nitrogen stripping and comprise: described Part II is fed to described end flash separator, and subsequently described Part II is decompressed to described flashing pressure.
9. according to method in any one of the preceding claims wherein, wherein said nitrogen stripping tower also comprises that gravity is higher than the inner rectifying of at least one of the described stripping portion section in described nitrogen stripping tower portion section, and described method also comprises:
-by the intermediate flow of the overhead vapor forming section condensation of the top section of the nitrogen stripping tower available from described rectifying portion section top, the intermediate flow of described partial condensation comprises condensate fraction and vapor fraction, described formation comprises by making described overhead vapor and auxiliary refrigerant stream heat exchange and thus heat being passed to auxiliary refrigerant stream with certain cooling load from described overhead vapor, thus overhead vapor described in partial condensation;
-under separating pressure, make described condensate fraction separate with described vapor fraction;
-make the part that at least refluxes of described condensate fraction enter the rectifying portion section in described nitrogen stripping tower from the level of described rectifying portion's section top.
10. according to method in any one of the preceding claims wherein, the wherein said described low temperature hydrocarbon compositions that provides comprises:
-make the charging steam that comprises hydrocarbon-containifirst incoming flow in low temperature heat exchanger with main refrigerant flow heat exchange, the charging steam of the described incoming flow of liquefying is thus to provide fluidized flow; And
-obtain described low temperature hydrocarbon compositions by described fluidized flow.
11. according to method in any one of the preceding claims wherein, it also comprises the by-passing part of described compressed vapour is optionally injected to described overhead vapor, the at least stripping portion section of walking around thus described nitrogen stripping tower, described by-passing part does not comprise stripping part.
12. according to method in any one of the preceding claims wherein, and it also comprises:
-extract steam recycle sections from described vapor fraction;
-described steam recycle sections is decompressed to flashing pressure;
-described steam recycle sections is injected to following at least one: through liquid, liquid hydrocarbon product stream and the process steam of nitrogen stripping.
13. according to method in any one of the preceding claims wherein, and wherein said vapor fraction comprises the nitrogen between 50mol% to 95mol%.
14. according to method in any one of the preceding claims wherein, and wherein said condensate fraction comprises the nitrogen that is less than 35mol%.
15. 1 kinds for removing the method for nitrogen from low temperature hydrocarbon compositions, described low temperature hydrocarbon compositions comprises the liquid phase containing nitrogen and methane, and described device comprises:
-being connected to the low temperature feeding line in the source of low temperature hydrocarbon compositions, described low temperature hydrocarbon compositions comprises the liquid phase containing nitrogen and methane;
-nitrogen stripping the tower that is communicated with described low temperature feeding line fluid, described nitrogen stripping tower comprises the inner stripping of at least one that be arranged in nitrogen stripping tower portion section;
-overhead vapor discharge pipe line, described overhead vapor discharge pipe line is communicated with described nitrogen stripping tower via the headroom in described nitrogen stripping tower;
-through the discharge pipe line of the liquid of nitrogen stripping, the discharge pipe line of the described liquid through nitrogen stripping is communicated with the liquid storage space in nitrogen stripping tower below the gravity of described stripping portion section;
-intermediate relief device in the discharge pipe line of the described liquid through nitrogen stripping, described intermediate relief device fluid is connected to described nitrogen stripping tower, and arrange in order to receive from the liquid storage space of described nitrogen stripping tower through the liquid of nitrogen stripping and by the described liquid pressure-reducing through nitrogen stripping, described intermediate relief device is at the stripping that comprises described nitrogen stripping tower on the interface on the pressure side and between flashing pressure side;
-be arranged at the liquid hydrocarbon product pipeline in described flashing pressure side, flow to discharge the liquid hydrocarbon product being produced by the described liquid through nitrogen stripping;
-be arranged at the process steam pipeline in described flashing pressure side, to receive the process steam being produced by the described liquid through nitrogen stripping;
-be arranged at the process compressor in described process steam pipeline, it arranges in order to receive described process steam and to compress described process steam, provide compressed vapour with the process compressor discharge place at described process compressor, described process compressor is at stripping on the described interface on the pressure side and between flashing pressure side;
-stripping vapor line, the level place of described stripping vapor line below the gravity of described stripping portion section is communicated with described nitrogen stripping tower fluid, and arranges in order to receive at least stripping part from the described compressed vapour of described process compressor;
-initial flow current divider in described low temperature feeding line, the setting of described initial flow current divider is in order to be divided into Part I by described low temperature hydrocarbon compositions and to have the composition identical with described Part I and the Part II of phase;
The-the first feeding line, described the first feeding line is for being sent to described nitrogen stripping tower from the Part I of described initial flow current divider;
The-the second feeding line, described the second feeding line is for being sent to from the Part II of described initial flow current divider as lower at least one: through liquid line, liquid hydrocarbon product pipeline and the process steam pipeline of nitrogen stripping, described the second feeding line is walked around described nitrogen stripping tower.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
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| EP11192921 | 2011-12-12 | ||
| EP11192921.2 | 2011-12-12 | ||
| PCT/EP2012/074958 WO2013087570A2 (en) | 2011-12-12 | 2012-12-10 | Method and apparatus for removing nitrogen from a cryogenic hydrocarbon composition |
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| CN103998882B CN103998882B (en) | 2016-04-13 |
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| CN (1) | CN103998882B (en) |
| AU (1) | AU2012350743B2 (en) |
| CA (1) | CA2858756C (en) |
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| CN114555208A (en) * | 2019-06-25 | 2022-05-27 | 马来西亚国家石油公司 | System and method for processing LNG |
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| US9441877B2 (en) | 2010-03-17 | 2016-09-13 | Chart Inc. | Integrated pre-cooled mixed refrigerant system and method |
| KR102312640B1 (en) | 2013-03-15 | 2021-10-13 | 차트 에너지 앤드 케미칼즈 인코포레이티드 | Mixed refrigerant system and method |
| US11428463B2 (en) | 2013-03-15 | 2022-08-30 | Chart Energy & Chemicals, Inc. | Mixed refrigerant system and method |
| US11408673B2 (en) | 2013-03-15 | 2022-08-09 | Chart Energy & Chemicals, Inc. | Mixed refrigerant system and method |
| US20150308737A1 (en) | 2014-04-24 | 2015-10-29 | Air Products And Chemicals, Inc. | Integrated Nitrogen Removal in the Production of Liquefied Natural Gas Using Intermediate Feed Gas Separation |
| US9945604B2 (en) * | 2014-04-24 | 2018-04-17 | Air Products And Chemicals, Inc. | Integrated nitrogen removal in the production of liquefied natural gas using refrigerated heat pump |
| US9816754B2 (en) | 2014-04-24 | 2017-11-14 | Air Products And Chemicals, Inc. | Integrated nitrogen removal in the production of liquefied natural gas using dedicated reinjection circuit |
| AR105277A1 (en) | 2015-07-08 | 2017-09-20 | Chart Energy & Chemicals Inc | MIXED REFRIGERATION SYSTEM AND METHOD |
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Also Published As
| Publication number | Publication date |
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| WO2013087570A3 (en) | 2014-05-01 |
| AU2012350743A1 (en) | 2014-05-22 |
| MY178855A (en) | 2020-10-21 |
| RU2014128650A (en) | 2016-02-10 |
| CA2858756C (en) | 2020-04-28 |
| CA2858756A1 (en) | 2013-06-20 |
| AU2012350743B2 (en) | 2015-08-27 |
| RU2622212C2 (en) | 2017-06-13 |
| WO2013087570A2 (en) | 2013-06-20 |
| CN103998882B (en) | 2016-04-13 |
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