Classifications

• • C—CHEMISTRY; METALLURGY
  • C01—INORGANIC CHEMISTRY
  • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
  • C01B3/00—Hydrogen; Gaseous mixtures containing hydrogen; Separation of hydrogen from mixtures containing it; Purification of hydrogen
  • C01B3/50—Separation of hydrogen or hydrogen containing gases from gaseous mixtures, e.g. purification
  • C01B3/56—Separation of hydrogen or hydrogen containing gases from gaseous mixtures, e.g. purification by contacting with solids; Regeneration of used solids
• • 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
  • B01D53/02—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 adsorption, e.g. preparative gas chromatography
  • B01D53/04—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 adsorption, e.g. preparative gas chromatography with stationary adsorbents
  • B01D53/047—Pressure swing adsorption
• • 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
  • B01D53/22—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 diffusion
  • B01D53/229—Integrated processes (Diffusion and at least one other process, e.g. adsorption, absorption)
• • C—CHEMISTRY; METALLURGY
  • C01—INORGANIC CHEMISTRY
  • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
  • C01B3/00—Hydrogen; Gaseous mixtures containing hydrogen; Separation of hydrogen from mixtures containing it; Purification of hydrogen
  • C01B3/50—Separation of hydrogen or hydrogen containing gases from gaseous mixtures, e.g. purification
  • C01B3/501—Separation of hydrogen or hydrogen containing gases from gaseous mixtures, e.g. purification by diffusion
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
  • C10G49/00—Treatment of hydrocarbon oils, in the presence of hydrogen or hydrogen-generating compounds, not provided for in a single one of groups C10G45/02, C10G45/32, C10G45/44, C10G45/58 or C10G47/00
  • C10G49/007—Treatment of hydrocarbon oils, in the presence of hydrogen or hydrogen-generating compounds, not provided for in a single one of groups C10G45/02, C10G45/32, C10G45/44, C10G45/58 or C10G47/00 in the presence of hydrogen from a special source or of a special composition or having been purified by a special treatment
• • B—PERFORMING OPERATIONS; TRANSPORTING
  • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
  • B01D—SEPARATION
  • B01D2256/00—Main component in the product gas stream after treatment
  • B01D2256/16—Hydrogen
• • B—PERFORMING OPERATIONS; TRANSPORTING
  • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
  • B01D—SEPARATION
  • B01D2257/00—Components to be removed
  • B01D2257/30—Sulfur compounds
  • B01D2257/304—Hydrogen sulfide
• • B—PERFORMING OPERATIONS; TRANSPORTING
  • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
  • B01D—SEPARATION
  • B01D2259/00—Type of treatment
  • B01D2259/40—Further details for adsorption processes and devices
  • B01D2259/40001—Methods relating to additional, e.g. intermediate, treatment of process gas
• • B—PERFORMING OPERATIONS; TRANSPORTING
  • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
  • B01D—SEPARATION
  • B01D2259/00—Type of treatment
  • B01D2259/40—Further details for adsorption processes and devices
  • B01D2259/40011—Methods relating to the process cycle in pressure or temperature swing adsorption
  • B01D2259/40043—Purging
  • B01D2259/4005—Nature of purge gas
  • B01D2259/40052—Recycled product or process gas
• • B—PERFORMING OPERATIONS; TRANSPORTING
  • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
  • B01D—SEPARATION
  • B01D2259/00—Type of treatment
  • B01D2259/40—Further details for adsorption processes and devices
  • B01D2259/40011—Methods relating to the process cycle in pressure or temperature swing adsorption
  • B01D2259/40043—Purging
  • B01D2259/4005—Nature of purge gas
  • B01D2259/40052—Recycled product or process gas
  • B01D2259/40054—Recycled product or process gas treated before its reuse
• • B—PERFORMING OPERATIONS; TRANSPORTING
  • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
  • B01D—SEPARATION
  • B01D2259/00—Type of treatment
  • B01D2259/40—Further details for adsorption processes and devices
  • B01D2259/40011—Methods relating to the process cycle in pressure or temperature swing adsorption
  • B01D2259/40058—Number of sequence steps, including sub-steps, per cycle
  • B01D2259/40062—Four
• • B—PERFORMING OPERATIONS; TRANSPORTING
  • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
  • B01D—SEPARATION
  • B01D2259/00—Type of treatment
  • B01D2259/40—Further details for adsorption processes and devices
  • B01D2259/40011—Methods relating to the process cycle in pressure or temperature swing adsorption
  • B01D2259/40077—Direction of flow
  • B01D2259/40079—Co-current
• • C—CHEMISTRY; METALLURGY
  • C01—INORGANIC CHEMISTRY
  • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
  • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
  • C01B2203/04—Integrated processes for the production of hydrogen or synthesis gas containing a purification step for the hydrogen or the synthesis gas
  • C01B2203/0405—Purification by membrane separation
• • C—CHEMISTRY; METALLURGY
  • C01—INORGANIC CHEMISTRY
  • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
  • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
  • C01B2203/04—Integrated processes for the production of hydrogen or synthesis gas containing a purification step for the hydrogen or the synthesis gas
  • C01B2203/042—Purification by adsorption on solids
  • C01B2203/043—Regenerative adsorption process in two or more beds, one for adsorption, the other for regeneration
• • C—CHEMISTRY; METALLURGY
  • C01—INORGANIC CHEMISTRY
  • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
  • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
  • C01B2203/04—Integrated processes for the production of hydrogen or synthesis gas containing a purification step for the hydrogen or the synthesis gas
  • C01B2203/0465—Composition of the impurity
• • C—CHEMISTRY; METALLURGY
  • C01—INORGANIC CHEMISTRY
  • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
  • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
  • C01B2203/04—Integrated processes for the production of hydrogen or synthesis gas containing a purification step for the hydrogen or the synthesis gas
  • C01B2203/0465—Composition of the impurity
  • C01B2203/0485—Composition of the impurity the impurity being a sulfur compound

Definitions

• the present invention relates to a process for treating a gaseous mixture comprising hydrogen, H 2 S and other compounds, such as hydrocarbons, aiming to separate the hydrogen from the other compounds of the mixture while at the same time keeping at the pressure of the initial gas mixture.
• the present invention relates to the treatment of products from hydrotreatment processes (HDT), very widespread in the refining industry.
• hydrotreatment processes Various types of hydrotreatment processes coexist in most refineries and process a large number of refinery products, in particular the following cuts: petrol, kerosene, diesel, vacuum distillates, oil bases.
• These hydrotreatment processes make it possible to adjust certain properties of the refined products such as sulfur, nitrogen, aromatic compounds or the number of cetane.
• Sulfur is often the key property (the units are also often called HDS for hydrodesulfurization) and is the subject of increasingly strict specifications leading refiners to seek ways of improving these units.
• the chemical hydrogenation reactions take place in a reactor where the hydrocarbon charge is mixed with a stream of hydrogen (in large excess) and passes over a catalytic bed. Part of the hydrogen reacts with sulfur, nitrogen and unsaturated organic compounds producing hydrogen sulfide (H 2 S), ammonia (NH 3 ), light hydrocarbons (HC) in CC 6 and more compounds heavy saturated.
• H 2 S hydrogen sulfide
• NH 3 ammonia
• HC light hydrocarbons
• recycling gas contains, in addition to hydrogen, most of the volatile compounds created in the reactor and which tend to concentrate there.
• make-up gas rich in hydrogen whose composition varies according to its mode of production.
• the hydrogen content of this gas (hereinafter referred to as make-up gas) varies between 70% by mole and 99.9% by mole, the remainder generally being methane or a mixture of light hydrocarbons.
• An essential parameter of the hydrotreatment reaction is the partial pressure of hydrogen leaving the reactor. This partial pressure depends on the total pressure of the unit (fixed during the "dimensioning" of the unit), the degree of vaporization of the hydrocarbon charge (fixed by the total pressure and the operating temperature) and especially of the concentration of hydrogen in the two make-up and recycling gases used.
• the partial pressure of H 2 S is a second important parameter which mainly depends on the H 2 S content of the recycling gas, therefore on the sulfur in the feed and the desulfurization rate applied during the hydrotreatment. It is therefore desirable in hydrodesulfurization units to increase the partial pressure of hydrogen and to reduce the partial pressure of H 2 S by purification of one or both of the make-up and recycling gases. The objective is then to reduce as much as possible the H 2 S and hydrocarbon contents.
• a first solution consists in purging the recycling gas in order to limit the concentration of H 2 S and of hydrocarbon thereof: a fraction of the recycling gas is taken to remove the noncondensable gases accumulated in the recycling loop. These gases are evacuated to the so-called "combustible gas"network; this network is present in all refineries and collects all the gaseous effluents recovered in the form of energy.
• this high-pressure purge has several disadvantages: • the impact on the partial pressures of hydrogen and H 2 S is low,
• the make-up gas is compressed to pass from the pressure of the hydrogen network to the operating pressure of the unit.
• the high pressure purge is therefore limited by the capacity of the makeup gas compressor.
• a second solution consists in implementing a step of washing the recycling gas with an amine solution.
• H 2 S is completely absorbed then desorbed by regeneration of the amine and finally transformed into liquid sulfur in a Claus unit placed downstream, for example.
• the washing only concerns H 2 S and does not remove any hydrocarbon from the recycling gas.
• the impact on pressure partial H 2 S is important, but the impact on the partial pressure of hydrogen is negligible.
• the gain in performance in hydrodesulfurization achieved by this washing therefore remains modest.
• amine solutions pose problems of corrosion and foaming.
• H 2 / CO / CH consists in purifying the hydrogen from the recycling gas by adsorption. This adsorption makes it possible to reach purity levels greater than 99.5%.
• the application of adsorption to a hydrodesulfurization recycling gas is for example described in JP 57055992.
• the treatment by adsorption of the recycling gas or of the mixture of the recycling gas or of the make-up gas influences the performance of the hydrodesulfurization significantly.
• this solution is never applied industrially to the treatment of these gases due to low yields.
• the hydrogen yield of adsorption units is generally between 70 and 90%. The loss of hydrogen must therefore be compensated by the use of a larger amount of make-up gas.
• a fourth solution of the prior art is the recovery of the hydrogen contained in the recycling gas by treatment of this gas with a membrane permeable to hydrogen.
• This type of membrane makes it possible to obtain good hydrogen purities (90 to 98%) and acceptable yields (80 to 98% depending on the desired purity). The cost is moderate compared to the previous solutions.
• This solution in the field of hydrodesulfurization units has been described in EP-A-061 259. This solution is applied industrially but the problem remains the need to recompress the recycling gas after it has passed through the membrane. Indeed, the purified hydrogen is produced at reduced pressure and the performance of the membrane is all the better as the production pressure is low. Full treatment of the recycling gas is in practice impossible.
• the membrane is therefore generally placed on a bypass of the recycle gas) and the hydrogen produced is returned to the suction of the makeup gas compressor to return to the unit pressure.
• the flow treated by the membrane, and consequently its efficiency, is once again limited by the capacity of the compressor of the make-up gas.
• a fifth solution is the use of membranes with reverse selectivity, which keep the hydrogen under pressure.
• these membranes have low hydrogen / hydrocarbon selectivities (particularly for the hydrogen / methane separation). They can therefore allow the complete treatment of the recycling gas (as described in US Patents 6,190,540 and US 6,179,996) to achieve a more selective purging of hydrocarbon, but a compromise between the loss of hydrogen and the degree of purification hydrogen must be found. If the objective is the thorough purification of the recycling gas (hydrogen purity of 90%, even 95%) then the hydrogen losses are very significant (30%, 50% or even much more) and the limitations are identical to those a simple purge (corresponding to the first solution mentioned above).
• the objective is to reduce the losses of hydrogen compared to a conventional high pressure purge (as in the first solution above), then the purification and the impact on the hydrodesulfurization performance are very moderate.
• the last drawback is that the loss of hydrogen varies with the composition of the recycling gas to be treated: it is all the greater when the recycling gas to be treated is rich in hydrogen.
• the object of the invention is to propose a process for treating the gas from a hydrodesulfurization unit so as to obtain a recycling gas having a high purity of hydrogen without reducing the pressure of the gas and without losing hydrogen during this treatment.
• the invention relates to a separation process by pressure-modulated adsorption of a gas mixture, in which a pressure modulation cycle comprising a succession of stages defining phases is implemented for the or each adsorber. adsorption, decompression, purge and pressure rise.
• the invention can be implemented with the so-called PSA cycles, in which the adsorption takes place at a pressure markedly higher than atmospheric pressure, typically of the order of 3 to 50 bars, while the minimum pressure of the cycle is substantially equal either to atmospheric pressure or to a pressure of a few bars.
• PSA cycles in which the adsorption takes place at a pressure markedly higher than atmospheric pressure, typically of the order of 3 to 50 bars, while the minimum pressure of the cycle is substantially equal either to atmospheric pressure or to a pressure of a few bars.
• the invention relates exactly to a method of treating a gas mixture comprising at least H 2 S and H 2 and having a pressure P using a treatment device comprising a pressure modulated adsorption unit (PSA) associated with an integrated compressor, in which there is implemented, for each PSA adsorber, a pressure modulation cycle comprising a succession of phases which define phases of adsorption, decompression, purging and pressure rise, in which :
• PSA pressure modulated adsorption unit
• the gaseous mixture to be treated is brought into contact with the adsorber bed so as to adsorb the different hydrogen compounds and to produce at the head of the l bed 'adsorber a gas essentially comprising hydrogen,
• recycle gas is either the compressed waste gas or the compressed purge gas.
• CPSA will designate the treatment device comprising a pressure modulated adsorption unit (PSA) associated with an integrated compressor implemented in the method according to the invention.
• PSA pressure modulated adsorption unit
• the method according to the invention aims to treat a gaseous mixture comprising at least H 2 S and H 2 which may be a stream resulting from a hydrodesulfurization process.
• This stream can also include hydrocarbons.
• the gaseous mixture to be treated has a temperature between 20 and 80 ° C, preferably between 30 and
• composition of this type of mixture is usually as follows:
• the gas mixture to be treated is brought into contact with a first bed of PSA adsorbent: the gas mixture is introduced into the lower part of the bed in the direction said to cocurrent.
• the most adsorbable compounds other than H 2 , essentially H 2 S and possibly the hydrocarbons if they are present in the gaseous mixture to be treated adsorb on the adsorbent and a gas essentially comprising hydrogen is produced at pressure P reduced by about one bar of pressure drop.
• the hydrogen produced is generally of a purity greater than at least 97% by mole, preferably greater than at least 99%, or even greater than at least 99.5%.
• the gas essentially comprising hydrogen obtained can be recycled in the hydrodesulfurization process because it has the hydrogen purity and the pressure necessary for this type hydrodesulfurization process.
• the adsorbent of the PSA beds must in particular allow the adsorption and the desorption of H 2 S and of heavy hydrocarbons such as pentane and hexane.
• the adsorbent bed is generally composed of a mixture of several adsorbents, said mixture comprising for example at least two adsorbents chosen from: active charcoals, silica gels, aluminas or molecular sieves.
• the silica gels must have a pore volume of between 0.4 and 0.8 cm 3 / g and a mass area greater than 600 m 2 / g.
• the aluminas have a pore volume greater than 0.2 cm 3 / g and a mass area greater than 220 m 2 / g.
• the zeolites preferably have a pore size of less than 4.2 ⁇ , a Si / Ai molar ratio of less than 5 and contain Na and K.
• the active carbons preferably have a mass area greater than 800 m 2 / g and a size of micropores between 8 and 20 A.
• each bed of PSA adsorbent is composed of at least three layers of adsorbents of different natures.
• Each lite of PSA adsorbent can comprise: in the lower part a protective layer composed of alumina and / or silica gel surmounted by a layer of activated carbon and / or carbon molecular sieve and optionally in the upper part of a layer of molecular sieve.
• the proportions vary according to the nature of the gaseous mixture to be treated (in particular according to its percentages of CH 4 and of hydrocarbons in Ca * .).
• a gas mixture free of water comprising 75% by mole d ⁇ 2, 5% C 3+ and 20% of light hydrocarbons (Ci-C 2), CO and N 2 can be treated with one unit of adsorption, the beds of which comprise at least 10% by volume of alumina and 15% by volume of silica gel in a low bed, the remainder being obtained by activated carbon.
• the decompression phase comprises a second step during which a gas compressed at the pressure P ′ ( ⁇ P), called co-current, is introduced into the adsorber bed recycle gas.
• P ′ a gas compressed at the pressure P ′
• co-current a gas compressed at the pressure P ′
• the compression of this recycle gas is carried out directly or indirectly by the compressor integrated into the CPSA.
• two streams can constitute this recycle gas, alone or as a mixture: the residual gas from the PSA which has been compressed, and the purge gas from the PSA which has been compressed.
• it is the purge gas and not the waste gas.
• the waste gas comes from the final stage of the PSA decompression phase and is partly compressed by the compressor integrated in the PSA of the CPSA treatment device while the purge gas comes from the PSA purge phase and is partly compressed by the same compressor integrated in the PSA before being used as recycle gas.
• These two gases both include hydrogen and essentially PH 2 S and possibly hydrocarbons, if the gas mixture to be treated contains them, but in different proportions. Their introduction into the bed of the adsorbent allows their reprocessing.
• the decompression phase of the process according to the invention also generally comprises at least a third step of co-current decompression of the adsorbent bed to a pressure P "( ⁇ P ') (this makes it possible to reduce the partial pressure by hydrogen from the internal gas phase of the adsorbent bed and to evacuate the hydrogen present in the dead volumes of the adsorber).
• This third decompression step co-current with the decompression phase produces a gas flow essentially comprising hydrogen, therefore of H 2 purity close to that of the gas resulting from the adsorption step described above, that is to say of hydrogen purity at least greater than 97 mol%.
• These gas streams comprising essentially hydrogen and produced during these second and third stages of the decompression phase are generally used:
• the co-current decompression step of the decompression phase during which a gas flow essentially comprising hydrogen is produced corresponds to the step during which the bed is introduced into the adsorber a gas compressed at pressure P '( ⁇ P) and coming from the compressor integrated into the treatment device, called recycle gas.
• the third step of the decompression phase of the process according to the invention also leads to the production of the PSA waste gas.
• this production of the waste gas can be obtained by counter-current decompression initiated at the pressure P "(- ⁇ P ') of the PSA.
• This waste gas essentially comprises H 2 S, or even hydrocarbons, and is poor in hydrogen, that is to say it has a quantity of hydrogen of less than 25 mol%.
• This waste gas can be evacuated from the process and burned or reused as recycle gas in the process according to the present invention as indicated above.
• the low cycle pressure having been reached, a purging phase is carried out to finalize the regeneration of the adsorber.
• a gas is introduced against the current in the adsorber and a purge gas is produced.
• This purge gas generally comprises between 40 and 85 mol% of H 2 .
• the gas introduced against the current into the adsorber during the purge phase is a gas flow originating from one of the stages of the decompression phase.
• Purge gas is generally used as recycle gas after recompression; it can be mixed with a secondary source of gas external to the CPSA and containing at least 30% by volume of hydrogen before being compressed.
• the purge gas and / or the waste gas coming from the compressor can be treated in whole or in part in a membrane permeable to hydrogen before being used as recycle gas.
• a hydrogen selective membrane is generally used which produces a permeate rich in hydrogen and a retentate rich in H 2 S and optionally in hydrocarbons depending on the nature of the gaseous mixture treated.
• It may be a polymer type membrane having a resistance to H 2 S, for example based on polyimide or polyaramide, preferably polyaramide (polyparaphenylene-therephthalamide).
• the permeate gas from the hydrogen permeable membrane can be mixed with one of the gas streams comprising essentially hydrogen from a co-current depressurization before its use in the purge phase.
• the pressure of the adsorber is increased by counter-current introduction of gas streams comprising hydrogen of pressure greater than P "such as the gas comprising essentially hydrogen produced at the pressure P during the adsorption phase and the gas essentially comprising hydrogen produced during different stages of the decompression phase.
• FIG. 1 illustrates an operating cycle of a CPSA of eight adsorbers (R01 to R08).
• the lines oriented by arrows indicate the movements and destinations of the gas flows, and, moreover, the direction of circulation in the adsorbers.
• the current is said to be current in the adsorber.
• the current enters the adsorber through the inlet end of this adsorber. If the arrow pointing upwards is located above the line indicating the pressure, the current leaves the adsorber through the outlet end of this adsorber, the inlet and outlet ends being respectively those of the gas to be treated and gas withdrawn during the production / adsorption phase.
• the current is said to be against the current in the adsorber.
• each adsorber R01 to R08 follows the cycle of FIG. 1, being offset with respect to the adsorber preceding it by a duration called “phase time” and equal to the duration T of the cycle divided by eight, that is to say divided by the number of adsorbers in function.
• the cycle of FIG. 1 therefore comprises eight phase times and illustrates the duality “phase time / adsorbers”, namely that at any time during the operation of the CPSA unit, each adsorber is in a different phase time.
• the gas to be treated is introduced into the adsorber R08 which enters a first step of the adsorption phase at the pressure P while the adsorber R07 begins the second step of the adsorption phase at this same pressure.
• a gas essentially comprising hydrogen is produced.
• the adsorber R06 is then in the decompression phase. It undergoes a first co-current decompression step up to the pressure P ': a gas flow is produced which is used for pressure balancing between the adsorbers R06 and R01.
• the recycle gas is introduced cocurrently into the adsorber R06.
• the different hydrogen compounds such as H 2 S and the hydrocarbons contained in the recycle gas are adsorbed and a gas essentially comprising hydrogen is produced: this is a recycling step.
• the hydrogen produced in R06 is used as the repressurization gas of the adsorber R02.
• the recycle gas is a gas compressed by the integrated compressor of the CPSA and coming, upstream of the compressor, from the adsorber R03 being in the purge phase.
• Decompression successive co-current of the adsorbers R04 and R05 makes it possible to descend from the pressure P 'to the pressure P "of saturation of the adsorber R04.
• the decompression is carried out in two phases: firstly by pressure balancing between the adsorbers R05 and R02, secondly by a successive co-current decompression of the adsorbers R05 and R04 to feed the downstream adsorber R03 in the purge phase
• the stage of production of the CPSA residual gas, very poor in hydrogen, is then initiated by counter-current depressurization of R04.
• the adsorber R03 undergoes a purge step at the lowest pressure of the cycle. is fed by the gas flow resulting from the co-current depressurization of the adsorbers R04 and R05.
• the adsorber R03 produces a purge gas which is composed of 40 to 85 mol% of H 2.
• the purge gas is compressed at pressure P 'by the compressor of the CPSA so era to form the recycle gas which is introduced cocurrently in the adsorber R06.
• This recycle gas can optionally be mixed with a secondary charge external to the process and / or be introduced into a hydrogen-permeable membrane before being introduced into R03.
• the membrane permeate, rich in hydrogen (purity of at least 80 mol%) is used to increase the productivity of the adsorbent by a more efficient purging of the adsorber R03: for this it is mixed with the gas flow resulting from the co-current depressurization of the adsorbers R04 and R05.
• the adsorbers R02 and R01 undergo a succession of steps of recompression by balancing and repressurization by recycling part of the hydrogen produced until reaching the adsorption pressure P at the end of compression of the adsorber R01.
• the operation of the CPSA during the other cycle phase times is deduced from the above operation: the adsorber R01, then the adsorber R02, and so on, until the adsorber R07 undergo the adsorption phase during the next phase time
• FIG. 2 represents the diagram of a conventional hydrodesulfurization unit (HDS): a charge of liquid hydrocarbon to be treated (1) and containing sulfur molecules is introduced into the hydrodesulfurization reactor (HDS reactor) in mixture with a gas flow essentially comprising hydrogen (7).
• HDS reactor hydrodesulfurization reactor
• numerous hydrogenation reactions take place and transform in particular organic sulfur molecules in hydrogen sulfide H 2 S.
• a biphasic flow (2) leaves the reactor, which is led to a high pressure separation unit producing two flows: a flow (3) essentially comprising hydrogen and H 2 S and a flow (21) mainly comprising hydrocarbons and H 2 S.
• the flow (21) is then generally expanded and treated in a low pressure separation unit producing two flows: a flow (22) comprising the hydrocarbons produced by the HDS unit and a stream (35) essentially comprising H 2 S.
• This latter stream (35) is injected into the acid fuel-gas network of the refinery.
• the flow (3) can be divided into two parts: - one (5) is compressed by the recycling compressor (C2) so that it can be reused in the HDS reactor: it is the recycling gas (6 )
• Line (33) includes a purge valve which can be opened, for example to regulate the pressure of the unit.
• the HDS unit is also supplied by a stream of fresh hydrogen (11) (this is make-up gas) which is taken from the hydrogen network of the refinery and then compressed by the make-up compressor ( C1), if necessary, up to the pressure of the HDS reactor to generate the flow (12).
• the compressed recycle gas (6) and the compressed make-up gas (12) form the stream of hydrogen-rich gas (7) introduced into the HDS reactor.
• the method according to the invention can be used to treat the gas mixture comprising hydrogen and H 2 S at high pressure (3) from the high pressure separation unit of the hydrodesulfurization unit.
• This variant is illustrated in FIG. 3.
• the gas mixture comprising hydrogen and H 2 S at high pressure (3) is introduced into the CPSA and treated according to the process of the invention.
• a hydrogen-rich gas (4) is recovered at the outlet of the adsorber bed, with a pressure drop of less than 1 bar, which can be sent to the recycling compressor (C2 ), then to the HDS reactor.
• C2 recycling compressor
• a residual gas (32) concentrating H 2 S and hydrocarbons is recovered which can supply one of the acid fuel-gas networks of the refinery.
• Line (33) can be opened to purge a fraction of the gas produced by the process according to the invention.
• Two optional modes can be implemented according to this first variant.
• all or part of the effluent from the low-pressure separation section (31) can be mixed with the purge gas from the CPSA purge phase before introduction into the CPSA compressor and then optionally into the CPSA membrane .
• the low pressure gas (31) can also come from another source having a hydrogen content of at least 30% by volume. This further reduces the hydrogen losses from the HDS unit.
• all or part of the hydrogen-rich gas from the CPSA (4 then 36) can be sent to the existing multi-stage booster compressor (C1) (for example between two compression stages).
• the method can be used to treat the gaseous mixture comprising hydrogen and H 2 S at high pressure (5) coming from the high pressure separation section when this mixture is at the suction of the recycling compressor (C2).
• This variant is illustrated in FIG. 4.
• the CPSA treats the gas mixture comprising hydrogen and H 2 S at high pressure (5) at the suction of the recycling compressor (C2) and the purifies to produce:
• waste gas (32) concentrating H 2 S and the hydrocarbons and supplying one of the acid fuel-gas networks of the refinery.
• the CPSA can treat, in addition to the gas mixture comprising hydrogen and PH 2 S at high pressure (5), all or part of the effluent from the low pressure separation section comprising essentially H 2 S (35 then 31), which further reduces the hydrogen losses from the HDS unit.
• all or part of the hydrogen-rich gas (4) from the CPSA can be sent to the existing multistage compressor (C1) (for example between two compression stages) so as to relieve the compressor from make-up (C2).
• the method can be used to treat the compressed recycling gas (6) at the outlet of the recycling compressor (C2). It purifies it to produce: - on the one hand, a hydrogen-rich gas (8), with a pressure drop of less than 1 bar, which is sent to the HDS reactor, and
• a waste gas (32) rich in H 2 S and in hydrocarbons which is directed to one of the acid fuel-gas networks of the refinery.
• This variant is illustrated in FIG. 5. It is possible to treat only part of the compressed recycling gas (6) due to the presence of a CPSA bypass line (41).
• the purge valve (33) can be opened (for example to regulate the unit pressure) and purge a fraction of the gas from the high pressure separation section.
• all or part of the effluent from the low pressure separation section essentially comprising HS (35 then 31) can be mixed with the purge gas from the adsorbent bed before introduction into the compressor and then optionally into the membrane. This further reduces the hydrogen losses from the HDS unit.
• the method can be used to treat the mixture (7) of the recycling gas (6) and the make-up gas (12) (coming from the hydrogen network).
• This variant is illustrated in FIG. 6.
• the process produces a gas essentially comprising hydrogen (8), with a pressure drop of less than 1 bar, which is sent to the HDS reactor, and a waste gas (32) concentrating H 2 S and hydrocarbons and supplying one of the refinery's acid fuel-gas networks.
• This configuration is useful when the purity of the make-up gas is low. It is possible to treat only part of the mixture (7) of the recycling gas (6) and the make-up gas (12) due to the presence of a bypass line (41).
• the purge valve (33) can be opened (for example to regulate the unit pressure) and purge a fraction of the gas from the high pressure separation section.
• all or part of the effluent from the low pressure separation section comprising essentially H 2 S (35 then 31) can be mixed with the purge gas from the adsorbent bed before introduction into the compressor and then optionally into the membrane. This further reduces the hydrogen losses from the HDS unit.
• the process of the invention makes it possible to achieve hydrogen yields on the recycling gas greater than 95%.
• the hydrogen selective membrane reduces the energy required to compress the purge effluent and increases the productivity of the adsorbent or reduces its size.
• the invention therefore allows purification of the recycle gas from a hydrodesulfurization unit combining both high purity (at least equal to 97% by mole), high yield (greater than 95%) and obtaining 'hydrogen under pressure (pressure difference between the gas mixture to be treated and the purified hydrogen obtained less than 1 bar).
• the method according to the invention therefore allows the integral treatment of the recycling gas, and possibly of the make-up gas.
• the impact induced on the refining unit is thus much greater than that obtained with any other solution of the prior art.
• the invention makes it possible to obtain in the hydrodesulfurization unit a partial pressure of hydrogen of between + 10% and + 60% and a partial pressure of H 2 S at the outlet of the reactor of between - 50% to - 80 %. This impact on partial pressures translates into an improvement in performance which can be expressed in different ways: - reduction of the sulfur level in the hydrocarbons produced in the hydrodesulfurization unit from -30% to - 80%,
• the table below gives a comparison of the results obtained during the use of a conventional PSA, of the implementation of the method according to the invention without a hydrogen selective membrane and with a hydrogen selective membrane, with identical adsorbent volume.
• the treated gas mixture is composed of: 90% by mole of H 2> 2% by mole of H 2 S and 8% by mole of hydrocarbons (including 4% by mole of CH 4 ).
• the adsorbent is a combination of at least two adsorbents taken from the following families: activated carbon, activated aluminas, silica gels, zeolites.
• the charge gas pressure is 35 bar.
• the waste gas pressure is bar.
• the average temperature of the adsorbent beds is 40 ° C.

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• Organic Chemistry (AREA)
• Oil, Petroleum & Natural Gas (AREA)
• General Chemical & Material Sciences (AREA)
• Chemical Kinetics & Catalysis (AREA)
• Combustion & Propulsion (AREA)
• Inorganic Chemistry (AREA)
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• Hydrogen, Water And Hydrids (AREA)
• Separation Of Gases By Adsorption (AREA)
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• Solid-Sorbent Or Filter-Aiding Compositions (AREA)
• Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

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  • 2002-02-15 FR FR0201915A patent/FR2836061B1/fr not_active Expired - Fee Related
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