CN100337722C - Configurations and methods for improved acid gas removal - Google Patents
Configurations and methods for improved acid gas removal Download PDFInfo
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- CN100337722C CN100337722C CNB028291336A CN02829133A CN100337722C CN 100337722 C CN100337722 C CN 100337722C CN B028291336 A CNB028291336 A CN B028291336A CN 02829133 A CN02829133 A CN 02829133A CN 100337722 C CN100337722 C CN 100337722C
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- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
- B01D53/1493—Selection of liquid materials for use as absorbents
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- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
- B01D53/1456—Removing acid components
- B01D53/1475—Removing carbon dioxide
Abstract
The present invention relates to equipment comprising an absorber (103). The present invention operates in a gas-phase supercritical region and eliminates an acid gas from feeding flow (9) at the high recovery rate of feeding flow (10), and high-purity acid gas flow (36) is generated simultaneously. Particularly optimized equipment comprises gas purifying equipment which receives at least 5 mole% of carbon dioxide and a feeding gas, and the pressure of the feeding gas is at least 3000 psi.
Description
Invention field
Field of the present invention is for removing sour gas from different gas streams.
Background of invention
From different gas streams, remove sour gas, especially from natural gas, remove carbon dioxide, become more and more important technology along with the increase of content of acid gas in the gas with various stream.For example, the carbon dioxide in natural concentration that gets with strengthening oily absorption method generally can be increased to about 60% from 10%.Have many known methods to remove sour gas in the prior art, all or nearly all method all can incorporate a kind of in following three types into.
In first type, can utilize one or more films physical separation sour gas from gaseous feed stream.Typical film system comprises pre-treatment skid and a series of membrane module.The film system is highly suitable for the processing to gas with various volume and product gas standard usually.And, film system relative compact, therefore making the film system is special feasible selection to marine gas treatment.Yet the film system is subject to the infringement of heavy hydrocarbons content of material in the feed gas.And, removing carbon dioxide and generally require multistage membrane separator and the recompression between each stage to relative low content, these are relatively more expensive comparatively speaking.
In second type, react to form sour gas complex compound (being typically non-covalent complex compound) with a kind of chemical solvent and sour gas.In the method that relates to the chemical reaction between sour gas and the solvent, unstripped gas is general uses as US3 563, the alkaline salt solution of 695 described weak inorganic acids is carried out gas washing, perhaps use as US2, the alkaline solution of 177,068 described organic acids or alkali carries out gas washing.These chemical reaction processes generally need the cooling of heat regeneration and chemical solvent, and often relate to the recirculation of a large amount of chemical solvents.Moreover, the required consumption of chemical solvent that absorbs ever-increasing sour gas can increase usually significantly, therefore, when content of acid gas in the feed gas increased along with the time, makes the use of chemical solvent become problem.
In the third type, use physical solvent from feeding gas, to remove sour gas, a large amount of sour gas and solvent reaction are wherein arranged.The Physical Absorption of sour gas mainly depends on the particular acid gas that will be removed (as CO
2Or H
2S) gaseous component uses and has the solvent of preferential solubility, and further depends on the pressure and temperature of solvent.For example, methyl alcohol can be used as low-boiling-point organic compound reason solvent, as US2, and the example in 863,527.But it is high relatively to cool off the input of required energy, and this technology generally shows the methane and the ethane of Duo than imagination and absorb, thereby needs lot of energy input for recompression and recovery.
As an alternative, can be in environment temperature or be lower than operating physical solvent under the environment temperature slightly, comprise as US2 926,751 described propene carbonate and US3,505,784 described N-methyl pyrrolidone or glycol ethers.Though these solvents can reduce the cooling requirement, most of absorption processes based on propene carbonate only limit to the absorption pressure (being subcritical pressure) less than 1000psi.Further in the known method, physical solvent also can comprise as US2,649,166 disclosed polyglycol ethers and the dimethoxy tetraethylene glycol that particularly points out, or as US3,773,896 described N-replace morpholine.Though use physical solvent to avoid some problem relevant at least, also cause many new difficulties with chemical solvent and film.Wherein, from high pressure charging gas, remove carbon dioxide and often be restricted to subcritical pressure.And, along with water content increases, may occur freezingly in the solvent circuit, therefore need high relatively temperature, thereby reduced the efficient of absorption process.On the other hand, physical solvent generally needs steam or external heat to make solvent reclamation, is suitable for removing sour gas to other very lean solvent of ppm level so that generate.
Therefore, although existing a lot of apparatus and method can remove sour gas from feeding gas, all or nearly all apparatus and method all have such or such shortcoming.So, still also have necessity that the method and apparatus that improves acid gas removal is provided.
The invention summary
The present invention is directed to the apparatus and method of the equipment that removes acid gas component from feed stream, wherein this feed stream comprises the carbon dioxide of 5mol% at least and has the pressure of 1000psi at least.
An aspect of theme of the present invention is, an equipment (plant) that contains absorber, this absorber is in gas phase supercritical region operation and receive the dehydration feeding gas that comprises at least 5 moles of % carbon dioxide, and wherein physical solvent absorbs in the absorber partial CO 2 at least contains at least 95 moles of % carbon dioxide with formation carbon dioxide stream.
Feeding gas in this device preferably is cooled to the above temperature of feeding gas hydrate point to remove most water content, and this cooled feed gas was dewatered in dewatering unit before entering absorber then.Further preferred feedstock gas (for example natural gas) pressure arrives about 5000psig for about 3000psig.
Especially preferred physical solvent comprises propene carbonate, and according to expection, absorber forms rich solvent by the physical solvent of step-down, therefore provides cooling to carbon dioxide stream, and the one-level hydrocarbon that is fed to absorber circular flow also is provided.In others, the rich solvent of step-down is further depressurized, thereby provides cooling to the solvent in the absorber, but also the secondary hydrocarbon that is fed to absorber circular flow is provided.Then, further the rich solvent of step-down can be emitted, and is separated into lean solvent and carbon dioxide stream in separator.
In generation place of hydrocarbon circular flow, estimate that this hydrocarbon circular flow will be compressed to the pressure of absorber in compressor, the merging circular flow that should compress can mix with the feeding gas of dehydration then.Lean solvent in the preferred embodiment can be handled in the coupling vacuum stripping unit with stripping gas, thereby is absorber regeneration physical solvent, but also generates fuel gas, simultaneously, but the product gas cooled feed gas in the absorber.Be not limited to theme of the present invention, further comprise at least 99% natural gas in the preferred product gas, and carbon dioxide stream be used to strengthen in the oily absorption method.
If product gas requires low-down acid gas standard, consider that then lean solvent in preferred embodiment comprises at least two kinds of logistics of coming out from vacuum stripper.The steam stripped solvent of part is the first half generation at stripper, and is pumped into the middle part of absorber; The lean solvent of the excessive stripping (ultra stripped) that comes out from the stripper Lower Half is cooled and is pumped into the top of absorber.This excessive steam stripped lean solvent configurations can be produced the product gas that satisfies ppm level acid gas standard, can only obtain by the solvent of heat regeneration and this rank acid gas is former.
Therefore, alternative aspects of the inventive subject matter, gas processing device can contain a kind of absorber, and this absorber receives the feeding gas that pressure is at least 1000psi and comprises at least 5 moles of % carbon dioxide.Wherein absorber adopts physical solvent to produce rich solvent and has consumed the product gas of carbon dioxide at least in part.Suitable device also can further comprise the stage turbine and the primary separator that separates one-level hydrocarbon composition from depressurized rich solvent to the rich solvent decompression, thus production one-level hydrocarbon circular flow and one-level rich solvent; The two-stage turbine machine is further to one-level rich solvent decompression, and the cooler utilization further the one-level rich solvent of decompression cool off physical solvent, the temperature range of wanting with the bottom temp of keeping absorber.In this device, the preferred one-level solvent that further is depressurized is separated in second-stage separator, this separator separates secondary hydrocarbon composition from the one-level solvent that further is depressurized, thereby produces secondary hydrocarbon circular flow and secondary rich solvent, and wherein firsts and seconds hydrocarbon circular flow enters absorber.
Thus, the method for equipment operation can comprise as next procedure, wherein provides absorber to receive the feed gas that pressure is at least 1000psi and contains sour gas.In another step, near small part sour gas removes from feed gas with physical solvent, thereby generates product gas and rich solvent; In another step, the pressure of rich solvent is lowered, and is fed to hydrocarbon circular flow in the absorber with formation, thereby generates depressurized rich solvent.In another step, depressurized rich solvent is used to cool off physical solvent, thereby the bottom temp of keeping absorber is in the temperature range of wanting and form hot depressurized rich solvent; In another step, hot depressurized rich solvent is separated into the logistics that contains to the small part sour gas, thereby forms lean solvent.In another step, this lean solvent is depressurized in the vacuum stripper, and at steam stripped lean solvent of this generating portion and excessive steam stripped lean solvent, the two is fed to two diverse locations of absorber.The overhead gas of stripper can be used as plant fuel gas.
The accompanying drawing summary
Fig. 1 is a schematic diagram of an exemplary configuration according to the inventive subject matter.
Fig. 2 is the schematic diagram of the lean solvent process of typical ultra stripped.
Detailed Description Of The Invention
The inventor finds that sour gas can be removed from high pressure and carbon dioxide content are at least the incoming flow of 5 moles of %, the method and apparatus that uses comprises an absorber, this absorber is in gas phase supercritical region operation and receive and contain the dehydrated feed gas that is at least 5 moles of % carbon dioxide, and wherein physical solvent absorbs partial CO 2 at least contains at least 95 moles of % carbon dioxide with formation carbon dioxide stream in absorber.
In the preferred structure described in Fig. 1, equipment contains feed cooler 100, and it can be cooled to 60 from 100 with feed gas 1, just more than feed gas hydrate point.The low-temperature receiver of cooler 100 provides (the absorber overhead gas stream that promptly leaves cooler through pipeline 44) by product gas 10, is generally-20 .Water in the feed gas 2 of cooling is removed (optional H at feed gas separator 101 via pipeline 5
2S removes bed can provide extra H
2S removes).The feed gas 4 of this partial dehydration and cooling is further dry in the dewatering unit 102 under high pressure (for example feed gas pressure) operation.Dehydrated feed gas 6 is further cooled to about 30 and mixes (seeing below) via pipeline 7 with merging circular flow 8 in cooler 100, be fed to the bottom of absorber 103 then via pipeline 9.Side cooler pump 104 is pumped into the position of rich solvent above gas feed tray the side cooler 105 of cooling rich solvent via pipeline 13 and 14.The rich solvent of cooling turns back to absorber via pipeline 15.
The coolant source of special preferential side cooler 105 is from the solvent-rich stream 20 (the further solvent-rich stream of decompression) of flash distillation, and it is from the secondary hydraulic turbine 109.Yet, will be appreciated that also and can replenish cooling by external source (for example via logistics 42).Therefore, the suitable cooler of configuration is kept constant absorber bottom temperature (for example 10 to 40 ) to absorb sour gas effectively.The one-level hydraulic turbine 106 is reduced to 350psig to 700psig with absorber bottom pressure, thereby rich solvent 12 is cooled to 5 to 35 , generates depressurized rich solvent stream 16.Flash distillation hydrocarbon vapour (one-level hydrocarbon circular flow 17) from primary separator 107 is recycled in the absorber 103 via recycle compressor 111.Cooler 108, cooled off from the carbon dioxide vapor 28 of separator 113 from the flashed solvent (one-level rich solvent 18) that primary separator 107 comes out.Optional extra cooling can be provided via logistics 40 by external source.Solvent in the pipeline 19 is cooled to about 0 to 30 , further with the secondary hydraulic turbine 109 about 150～300psig that reduces pressure, simultaneously one-level rich solvent 18 is cooled to-2 to 28 approximately, therefore forms the solvent-rich stream 20 of further depressurized.The solvent-rich stream 20 of further depressurized is used to provide the cooling requirement of side cooler 105 then.After leaving side cooler 105, solvent-rich stream 24 is separated in second-stage separator 110, and is recycled to the absorber via recycle compressor 111 from the flash distillation hydrocarbon vapour (secondary hydrocarbon circular flow 25) that second-stage separator 110 comes out.Recycle compressor 111 is emitted logistics 8 (promptly merging circular flow) to cooler 121, mixes then with from the cooling of pipeline 7 and the feed gas of dehydration, forms to be merged into materials flow 9 and to be fed to absorber 103.
The flashed solvent (secondary rich solvent 26) of coming out from second-stage separator 110 is by reduce pressure pipeline 27 and be the separator 113 of operation under the atmospheric pressure separated of JT valve 112.Flash vapors (carbon dioxide stream) from the logistics 28 that separator 113 (operating to 0 at-23 ) comes out will contain the CO more than 95%
2Cold-producing medium in the logistics 28 is recovered in cooler 108.The flash vapors that heats up is used to strengthen oil via pipeline 22 and reclaims, and poor (flash distillation) solvent liquid 29 that comes out from separator 113 is by JT valve 114 logistics 30 that reduces pressure.
If product gas requires to reach ppm level acid gas standard, then can use excessive stripping solvent device shown in Figure 2.This device is general to comprise an advanced stripper device based on demonstration plant shown in Figure 1, and it can be sour gas and absorbs the ultra-poor solvent of production.Stripper generally has the first half 200 and the latter half 116, and the two is collected 201 on dish and separates.Stripping part 200 produce parts steam stripped, collect the solvent in the catch tray 201.Logistics 201 generally accounts for 50% to 80% of total solvent flow, and it is extracted out from catch tray 201 by lean solvent pump 203, and is fed to the middle part of absorber 103.Residual stream 211 generally accounts for 20% to 50% of total solvent flow, and it generally is heated to about 55 with feed gas stream 9 in heat exchanger 203.Feed gas cools off in heat exchanger 203 and generates generally in the logistics 214 of-10 to 20 .Because gas has been dried at dewatering unit 102, so the freezing of water all is out of question under all or nearly all situation.Therefore, it should be particularly noted that integrated stripper produces two stripping solvent streams that are fed to the absorber different parts, thereby by partly keeping the height ratio of steam and liquid to generate very lean solvent at the lower semisection stripping.
About suitable feed gas, expect that many natural and synthetic feed gas all are fit to.But the feed gas, the especially carbon dioxide content that preferably include natural gas especially are at least about the natural gas of 5 moles of %, and more typical is at least about 10 moles of %, and most typical is at least about 20 moles of %.Therefore, especially suitable incoming flow comprises from the oil field, for example the natural gas feed stream of Alaska PrudhoeBay and Norway Orman Lange.Equally, the sour gas content of suitable feed gas (especially carbon dioxide content) may be different, and can mainly depend on the source of feed gas.But general preferred acidic gas content is at least about 5 moles of %, and more typical is at least about 10 moles of %, and most typical is at least about 20 moles of %.Typical incoming flow is formed and is listed in the table below in 1.
| Mole % | |
| N 2 | 0.88 |
| CO 2 | 19.14 |
| H 2S | 0.00 |
| C 1 | 72.69 |
| C 2 | 5.29 |
| C 3 | 1.40 |
| iC 4 | 0.22 |
| nC 4 | 0.26 |
| iC 5 | 0.02 |
| nC 5 | 0.01 |
| C 6 | 0.08 |
Table 1
And, will be appreciated that also the pressure of the feed gas of expection may alter a great deal, suitable pressure can be in the scope between atmospheric pressure and several thousand psi.Yet special preferred feedstock gas pressure is at least 1000psig, and more typical is 2000psig at least, and especially more typical is at least about 3000psig, and most typical is at least about 5000psig.Moreover,, will be appreciated that also that pressure also can increase by one or more compressors as required though generally generally believe the pressure that depends on the contained gas of oil well to the pressure of small part feed gas.
In further contemplated aspects, incoming flow was cooled before entering absorber, and the small part that is cooled to of special preferred feedstock stream is implemented by the product gas in the heat exchanger (being absorber overhead stream).Consider the cooling degree, estimate that generally incoming flow can be cooled to different temperatures.But general preferred feedstock stream can be cooled to the temperature more than gas hydrate point just.Therefore, the feed gas stream of cooling can be fed to separator, can remove from the incoming flow of cooling and form the partial dehydration feed gas to small part moisture in this separator in the feed gas.Formed partial dehydration feed gas can be further dehydrated at dewatering unit then, will be appreciated that existing all gas dewatering unit is all applicable.For example, further dehydration can be implemented by spent glycol or molecular sieve.In a further preferred aspect, the expection dehydrated feed gas can be further cooled before entering absorber.In particularly preferred imagination device, the feed gas of dehydration is cooled in heat exchanger, wherein provides refrigeration by product gas (being absorber overhead stream).Because absorption process can be in unusual low temperature (for example in the absorber for-20 to 40 ) anhydrous freezing come out in the circulation of operation solvent down, so the dehydration of feed gas is particularly useful.Be with acid gas removal in very low-level preferred imagination device, the gas of dehydration can be used to further cool off from the excessive steam stripped lean solvent of part of stripping process.And absorber bottom is moved at low temperatures absorber is operated under minimizing solvent loop condition, thereby increases efficient.
Further preferred device may comprise additionally that sulphur removes unit (for example pass through clean-up bed or have concrete certain additional absorber at the solvent of sulphur), and specially designed sulphur removes the unit can remove the partial vulcanization hydrogen that contains in the feed gas (for example at position, absorber upper reaches) at least.Perhaps, utilize excessive stripper plant (seeing above), this process can be produced the processing gas with very low content of acid gas and be need not the help that sulphur removes the unit.
Therefore, should be especially recognized that suitable absorber is to operate under high relatively pressure, especially Yu Qi high pressure is 1000psi at least, is typically 2000psi at least, and more typical is 3000psi at least, and most typical is 5000psi at least.Therefore, the absorber that will be appreciated that imagination will move in gas phase supercritical region." in the gas phase supercritical region operation " here refers to move absorber under the following conditions: the non-existent supercriticality of liquid and gas that wherein will be in physics to small part feed gas (if not whole feed gas).And, by in gas phase supercritical region operation absorption process, can avoid the condensation of hydro carbons usually, and this serious problem normally in existing technology so far.In further design conditions, the type of absorber needn't be subjected to the restriction of certain concrete structure, and all known absorption devices structures all are adapted at using here.But, preferably include the contact arrangement that packed bed or dish are constructed especially.
About used solvent in the absorber of design, will be appreciated that all physical solvents and composition thereof all are suitable.Countless physical solvents is arranged in the prior art, comprise methyl pyrrolidone, NHD and/or the various polyethylene glycol dialkyl ether of propene carbonate, tributyl phosphate, routine as the preferred physical solvent of demonstration.Alternative other solvent comprises enhanced tertiary amine (for example piperazine) or uses other the solvent that similar performance can be arranged with physical solvent.
Therefore, absorber will provide and reduce the product gas that sour gas has especially reduced carbon dioxide.And, will be appreciated that because absorber receives the feed gas of cooling and dehydration, product gas generally can meet all or nearly all pass through commercial gas standard and the requirement that pressure piping is carried, perhaps as the feed gas of LNG equipment.Especially should further be appreciated that, rich solvent in the absorber can leave absorber bottom (1000psi at least for example with relatively high pressure power, relatively be typically between 2000 to 5000psi), therefore can be used for the different logistics of acting (for example producing electric energy) and/or refrigerated separation process.In particularly preferred device, rich solvent is to use the one-level hydraulic turbine to emit to produce mechanical energy or electric energy under pressure, the rich solvent of decompression is separated into the one-level circular flow and the one-level rich solvent of hydrocarbonaceous then in separator, it is subsequently by carbon dioxide stream (wherein carbon dioxide is produced by feed gas) cooling.The one-level circular flow of hydrocarbonaceous is preferably recycled to absorber, and the one-level rich solvent is further reduced pressure to produce mechanical energy and electric energy by the secondary hydraulic turbine again.Further the rich solvent of decompression then in heat exchanger (the side cooler of preferred absorbers) be used as cold-producing medium, thereby the cooling rich solvent keeps the absorber bottom temperature wanted in absorber.Behind over-heat-exchanger, this solvent-rich stream that further reduces pressure is separated into the secondary rich solvent and is recycled to separator in second-stage separator secondary hydrocarbonaceous circular flow.Therefore, will be appreciated that solvent-rich stream is used for producing work done and/or the cooling that at least one uses high pressure before rich solvent flash distillation and regeneration.
The flash distillation of rich solvent can be implemented in different device, estimates that generally all conventional device all are adapted at this use.Yet, general preferred rich solvent (provide work done and/or the cooling after) under pressure, further emit, up to the pressure that enough discharges at least 80% (be typical at least 90%, be typically at least 95% most) carbon dioxide dissolved.The carbon dioxide of Sheng Chaning (is generally operated under normal pressure) in separator then and is separated from lean solvent like this.Especially should be appreciated that the carbon dioxide content of the carbon dioxide stream that generates like this surpasses 90%, is typical at least 95%.So the carbon dioxide stream of Xing Chenging is particularly useful for strengthening oily absorption method thus.
In the further contemplated aspects of theme of the present invention, the lean solvent that comes out from separator further is released further to be fed in the vacuum separator through the JT valve under pressure.Preferred vacuum separator is operated under the pressure between about 0.7～7.0psia, and this pressure is produced by liquid sealed vacuum pump.Residual carbon dioxide in the lean solvent (general purity is at least 95%) is removed in vacuum separator, also will be used to strengthen oily absorption method as shown in Figure 1.Physical solvent is regenerated in stripper and is looped back absorber through lean solvent pump then.In particularly preferred structure, stripper utilizes depleted gas (for example portion of product gas) to produce fuel gas as stripping gas.But in replaceable structure, all gases except product gas also is suitable, and this is included in this equipment interior gas and even nitrogen or air from other logistics.Further should be understood that, in this structure, use vacuum separator and gas stripper to combine and to produce CO
2Concentration is generally less than the very lean solvent of 1000ppmv.
Aspect further envisioning, especially to be processed to the occasion of ppm level acid gas standard at gas, excessive stripping solvent configuration can comprise comprising at least to be collected coils the two-part advanced stripper that separates, it produces part stripping solvent and excessive stripping solvent, and the two is fed to the diverse location of absorber respectively.Should further recognize, in this structure, use vacuum separator and excessive stripper to combine and to produce CO
2Concentration is generally less than the ultra-poor solvent of 100ppmv.
Therefore, contain the occasion of natural gas, be to be understood that product gas contains at least 90%, relatively be typically at least 95%, be typically the feed gas of at least 99% natural gas most at particularly preferred structure and feed gas.Though do not wish to be fettered by any theory and hypothesis, to reclaim be by at least one is provided to relatively so high natural gas in the expection product gas, and more preferably two hydrocarbonaceous circular flows turn back to absorber and finish.Therefore, the purity of the carbon dioxide that produces stream high relatively, and the carbon dioxide that forms thus stream typically will contain at least 90%, more typically be at least 95% CO
2
The circulating air compressor that is fit to is firsts and seconds hydrocarbonaceous recycle gas stream can be compressed to equal or be equivalent to cool off and all compressors of the feed gas pressure of dewatering.Similarly, estimate that lean solvent pump will be for guiding to lean solvent the solvent pressure that provides suitable in the absorber.
Therefore, an equipment can comprise the absorber that receives feed gas, this feed gas pressure is at least 1000psi and contains the carbon dioxide of at least 5 moles of %, and wherein absorber Applied Physics solvent produces a kind of rich solvent and a kind of product gas that has consumed carbon dioxide to small part.The equipment of imagination can further contain the level steam turbine and the primary separator that one-level hydrocarbon composition is separated with the rich solvent decompression from the rich solvent of decompression, produce one-level hydrocarbon circular flow and one-level rich solvent thus, two level steam turbines further reduce pressure to the one-level rich solvent, the temperature range that physical solvent is being wanted with the bottom temp that keeps absorber is cooled off in the cooler utilization further one-level solvent of decompression, wherein further the one-level solvent of decompression is separated in second-stage separator, this separator is isolated secondary hydrocarbon composition from the one-level solvent of further decompression, generate secondary hydrocarbon circular flow and secondary rich solvent therefrom, firsts and seconds hydrocarbon circular flow wherein turns back to absorber.
About feed gas, absorber, physical solvent, carbon dioxide stream and other various components, identical Consideration discussed above all is suitable for.Therefore expect especially that feed gas is partly dewatered by product gas at least and cools off, and before entering absorber, be further dehydrated at dewatering unit.Moreover, the one-level rich solvent of expection can be by the cooling of carbon dioxide stream, and the secondary rich solvent of expection can be further depressurized to be removed to the small part carbon dioxide, thereby (it can be further processed in a vacuum separator to form lean solvent, this vacuum separator utilizes depleted gas and generates fuel gas, thus the regeneration physical solvent).The physical solvent of special expection comprises propene carbonate, and especially preferably carbon dioxide is used to strengthen oily absorption method.
Therefore, the method for equipment operation can comprise as next procedure, wherein provides absorber to receive the feed gas that pressure is at least 1000psi and contains sour gas.In another step, near small part sour gas removes from feed gas with physical solvent, thereby generates product gas and rich solvent; In another step, the pressure of rich solvent is reduced to form the hydrocarbon circular flow and to be fed to absorber, herewith generates depressurized rich solvent.In another step, depressurized rich solvent is used to cool off physical solvent, thereby the bottom temp of keeping absorber is in the temperature range of wanting and form hot depressurized rich solvent; In another step, hot depressurized rich solvent is separated into the logistics that contains to the small part sour gas, thereby forms lean solvent.
About feed gas, absorber, physical solvent, carbon dioxide stream and other various components, identical Consideration discussed above all is suitable for.Therefore expect especially that feed gas pressure arrives between about 5000psi at about 3000psi.The sour gas of expection especially comprises carbon dioxide, and physical solvent comprises propene carbonate.The aspect that further contemplates that is handled lean solvent in vacuum separator with depleted gas, thereby generates the physical solvent of fuel gas and regeneration.
Therefore, with the CO of traditional high feed gas pressure of using amine, other physical solvent or film
2Removing process is compared, and the structure that is contemplated to according to the inventive subject matter can greatly reduce total power consumption and capital cost.Moreover, the structure of this expection and technology generally will no longer need thermal source, therefore can further cut down the consumption of energy.Furtherly, strengthen oily recycling engineering and will run into CO in the feed gas continually
2Concentration increases, and generally is increased to 60% from 10%.The structure of expection and technology can adapt to these changes and have substantially the same solvent circulation.
And, since be operate at low temperatures and physical solvent in moisture few, the structure of expection generally can provide non-corrosive technology.In contrast, more complicated is operated and kept to traditional amine device that removes carbon dioxide usually, and this is because these technologies are easy to corrosion and often need anti-foam and anticorrosive injection during operation.Furtherly, different with the amine method, another advantage of contemplated physical solvent process is that solvent circulation rate is to CO
2The dividing potential drop increase is insensitive (for example will be handled and contain 20%CO
2The desired physical solvent speed of 100MMSCFD gas contain 60%CO with will handling basically
2100MMSCFD gas desired identical.CO
2Load in solvent is only along with CO in the feed gas
2The increase of concentration and increasing.In the amine technological design, because CO
2Load in rich amine solvent must be kept, so the cycle rate of amine can increase about 3 times).
Compare with existing amine processing method, contemplated physical solvent process also has another advantage, is exactly that it is simple and anti-freezing, therefore needs a spot of supportive off-side facility and application system, as steam boiler.For example, contemplated structure typically only needs refrigeration, and, if remaining CO
2Content is between 5～10psia, and the inventor estimates that the operation of equipment just makes solvent reclamation without thermal oil system.Moreover, when at high relatively CO
2When feed gas was operated down, solvent cooled off desired refrigeration and just can be completely removed, and this is because from CO in the solvent reclamation
2The flash distillation meeting necessary cooling is provided.
Another advantage of the present invention is to handle the feed gas standard that satisfies the requirement of LNG equipment, this standard-required CO
2At 50ppmv scope, H
2S is in the 4ppmv scope.The included content of excessive stripping apparatus that the present invention describes can directly be used.
Thus, the structure of raising acid gas removal and the specific embodiments and applications of method are carried out in this disclosure.For a person skilled in the art, the many variations except that those disclosed technology all are possible, and do not exceed notion of the present invention herein yet significantly.Therefore, except that the expection claim of appendix, theme of the present invention is not restricted.And when understanding the claim of specification and expection, all words all should be understood as that implication the most widely as much as possible under situation consistent with the context.Particularly, " contain " and " comprising " these two speech should be understood to relate to element, composition or step non-limitingly, show related element, composition or step can with other not in this element that specially relates to, composition or step 1 with existence or use or combine.
Claims (26)
1. equipment that is included in the absorber of gas phase supercritical region operation, absorber in this equipment receives the dehydrated feed gas that comprises at least 5 moles of % carbon dioxide, and wherein physical solvent absorbs in the absorber at least partial CO 2 and forms the carbon dioxide stream that contains at least 95 moles of % carbon dioxide.
2. according to the equipment of claim 1, wherein feed gas is cooled to the above temperature of feed gas hydrate point, and wherein Leng Que feed gas dewatered in dewatering unit before entering absorber.
3. according to the equipment of claim 1, wherein feed gas pressure is 3000psi at least.
4. according to the equipment of claim 1, wherein feed gas comprises natural gas.
5. according to the equipment of claim 1, wherein physical solvent comprises propene carbonate.
6. according to the equipment of claim 1, wherein absorber generates rich solvent, and rich solvent is depressurized, and the rich solvent of decompression separates the one-level hydrocarbon circular flow that generation is further flowed the one-level rich solvent of cooling by carbon dioxide and is fed to absorber.
7. according to the equipment of claim 6, wherein the one-level rich solvent is further depressurized, provide cooling to the physical solvent in the absorber thus, the one-level rich solvent of described further decompression is through separating the secondary hydrocarbon circular flow that generates the secondary rich solvent and be fed to absorber.
8. according to the equipment of claim 7, wherein the secondary rich solvent is emitted, and is separated into lean solvent and carbon dioxide stream in separator.
9. according to the equipment of claim 7, wherein use compressor compresses firsts and seconds hydrocarbon circular flow, the feed gas of wherein compressed firsts and seconds hydrocarbon circular flow and dehydration merges.
10. equipment according to Claim 8, wherein lean solvent is handled in vacuum separator/stripper combination with depleted gas, is absorber regeneration physical solvent thus, but also the generation fuel gas.
11. according to the equipment of claim 2, wherein absorber produces the product gas that at least partly removes carbon dioxide, and wherein feed gas is cooled off by product gas.
12. according to the equipment of claim 11, wherein feed gas comprises natural gas, and wherein product gas contains at least 99% natural gas.
13. according to the equipment of claim 1, wherein carbon dioxide stream is used to strengthen the oil recovery.
14. an equipment contains:
Receive the absorber that pressure is at least 1000psi and comprises the feed gas of at least 5 moles of % carbon dioxide, wherein absorber adopts physical solvent to produce rich solvent and at least partly removes the product gas of carbon dioxide;
Be used for a stage turbine of depressurized rich solvent and the primary separator that separates one-level hydrocarbon composition from depressurized rich solvent, produce one-level hydrocarbon circular flow and one-level rich solvent thus;
Thereby the two-stage turbine machine of the one-level rich solvent that is used for further reducing pressure and use further the one-level rich solvent of decompression and cool off physical solvent and keep the cooler of absorber bottom temperature in the temperature range of wanting;
Wherein further the one-level rich solvent of decompression separates in second-stage separator, this second-stage separator separates secondary hydrocarbon composition from the one-level rich solvent of further decompression, produce secondary hydrocarbon circular flow and secondary rich solvent thus, and wherein firsts and seconds hydrocarbon circular flow is fed to absorber.
15. according to the equipment of claim 14, wherein feed gas before entering absorber at least by partial dehydration.
16. according to the equipment of claim 15, wherein feed gas is to be cooled off by product gas before entering absorber and dehydrated at dewatering unit.
17. according to the equipment of claim 14, wherein the secondary rich solvent is further depressurized to remove partial CO 2 at least, forms lean solvent and carbon dioxide stream thus.
18. according to the equipment of claim 17, wherein the one-level rich solvent is by the cooling of carbon dioxide stream.
19. according to the equipment of claim 18, wherein lean solvent is further processed in stripper, this stripper is used stingy and is generated fuel gas, the physical solvent of regenerating thus.
20. according to the equipment of claim 18, wherein physical solvent comprises propene carbonate.
21. according to the equipment of claim 17, wherein carbon dioxide stream is used to strengthen the oil recovery.
22. according to the equipment of claim 14, it further comprises and has the stripper that is collected at least two stripping sections separating of dish, wherein stripper regeneration physical solvent.
23. an equipment operation method comprises:
Provide to receive the absorber that pressure is at least the feed gas of 1000psi, wherein feed gas contains sour gas;
From feed gas, be removed to the small part sour gas with physical solvent, generate product gas and rich solvent thus;
The pressure that reduces rich solvent generates the rich solvent of decompression, and it separates the back and forms one-level hydrocarbon circular flow and the one-level rich solvent that is fed to absorber;
Reduce the pressure of one-level rich solvent, utilize the one-level rich solvent cooling physical solvent of decompression, keep absorber bottom temperature also forms heat in the temperature range of wanting decompression one-level rich solvent thus;
The decompression one-level rich solvent of heat is separated into secondary hydrocarbon circular flow and the secondary rich solvent that is fed to absorber;
The secondary rich solvent is separated into the logistics that contains to the small part sour gas, forms lean solvent thus.
24. according to the method for claim 23, wherein the pressure of feed gas at 3000psi between the 5000psi.
25. according to the method for claim 23, wherein sour gas is a carbon dioxide.
26. according to the method for claim 23, wherein physical solvent comprises propene carbonate.
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| PCT/US2002/012050 WO2003089115A1 (en) | 2002-04-15 | 2002-04-15 | Configurations and methods for improved acid gas removal |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN1627980A CN1627980A (en) | 2005-06-15 |
| CN100337722C true CN100337722C (en) | 2007-09-19 |
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| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CNB028291336A Expired - Fee Related CN100337722C (en) | 2002-04-15 | 2002-04-15 | Configurations and methods for improved acid gas removal |
Country Status (6)
| Country | Link |
|---|---|
| JP (1) | JP4771663B2 (en) |
| CN (1) | CN100337722C (en) |
| AU (1) | AU2002307364C1 (en) |
| CA (1) | CA2482159C (en) |
| MX (1) | MXPA04010112A (en) |
| WO (1) | WO2003089115A1 (en) |
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| US8784761B2 (en) | 2009-11-20 | 2014-07-22 | Alstom Technology Ltd | Single absorber vessel to capture CO2 |
| US8790605B2 (en) | 2009-09-15 | 2014-07-29 | Alstom Technology Ltd | Method for removal of carbon dioxide from a process gas |
| US8518156B2 (en) | 2009-09-21 | 2013-08-27 | Alstom Technology Ltd | Method and system for regenerating a solution used in a wash vessel |
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| US8293200B2 (en) | 2009-12-17 | 2012-10-23 | Alstom Technology Ltd | Desulfurization of, and removal of carbon dioxide from, gas mixtures |
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| DE102015013796A1 (en) * | 2015-10-22 | 2017-04-27 | Linde Aktiengesellschaft | Process and apparatus for recovering gas products |
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- 2002-04-15 JP JP2003585859A patent/JP4771663B2/en not_active Expired - Fee Related
- 2002-04-15 CA CA002482159A patent/CA2482159C/en not_active Expired - Lifetime
- 2002-04-15 CN CNB028291336A patent/CN100337722C/en not_active Expired - Fee Related
- 2002-04-15 AU AU2002307364A patent/AU2002307364C1/en not_active Ceased
- 2002-04-15 WO PCT/US2002/012050 patent/WO2003089115A1/en active IP Right Grant
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Also Published As
| Publication number | Publication date |
|---|---|
| MXPA04010112A (en) | 2004-12-13 |
| AU2002307364B2 (en) | 2007-05-31 |
| AU2002307364A1 (en) | 2003-11-03 |
| JP2005522326A (en) | 2005-07-28 |
| WO2003089115A1 (en) | 2003-10-30 |
| AU2002307364C1 (en) | 2008-07-10 |
| CA2482159A1 (en) | 2003-10-30 |
| CN1627980A (en) | 2005-06-15 |
| JP4771663B2 (en) | 2011-09-14 |
| CA2482159C (en) | 2009-08-11 |
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