Patent Application
20230331547
The present invention is in the field of syngas treatment and relates to a sorption-enhanced water-gas shift (SEWGS) process for the formation of a CO2 product stream and an H2 product stream which requires much less steam than conventional processes.
Energy-intensive sectors such as steel, refining and chemical industries are still largely dependent on fossil fuels and raw materials, so that it remains important to capture and reuse the released CO2. Unused CO2 can be stored safely, for example in depleted natural gas fields in the North Sea. In the long term, negative CO2 emissions may become the target, which can be obtained by, for example, storing the released CO2 in the use of biomass. The overall reduction in the CO2 emitted into the atmosphere is one of the major challenges in the present-day society, especially for industries where large amounts of carbon atoms remain as side-product, which are typically emitted as CO2.
Sorption-enhanced water-gas shift (SEWGS) has been developed for the conversion of CO to H2 and CO2, allowing the formation of a CO2 product stream and an H2 product stream, wherein CO2 is captured by means of adsorption, and can then be stored or reused. This process can be employed to purify the H2 gas in a syngas mixture containing CO and/or CO2, to obtain a H2 product stream and a by-product stream wherein the incoming carbon atoms are captured in a CO2 stream. The CO2 product stream may then be subjected to CO2 storage and as such eliminate CO2 emissions into the atmosphere.
In the art, high-pressure steam supply in hydrogen production processes is made more efficient by a water gas shift process which comprises (i) a reaction stage wherein a feed gas comprising CO and H2O is fed into a water gas shift reactor column containing a sorbent material capable of adsorbing CO2 and wherein a product gas issuing from the reactor is collected, (ii) a rinse stage wherein high pressure steam is fed to the column, (iii) one or more pressure equalisation steps wherein the high-pressure column is connected to a column in another stage of the cycle at lower pressure and requiring repressurisation, (iv) a blowdown step wherein the pressure in the column is reduced to the regeneration pressure, (v) a regeneration stage wherein H2O is fed (i.e. a purge stage) and CO2 is removed from the reactor, (vi) one or more pressure equalisation steps wherein the column is repressurised with gas from a column at a higher pressure in another stage of the cycle and requiring depressurisation, and (vii) a final repressurisation step in which the pressure in the column is raised to the reaction stage pressure.
Existing SEWGS processes operate economically under steam consumption constraints. SEWGS cycle design therefore involves minimising the steam consumption during the rinse and purge stages while achieving desirable product specifications in terms of e.g. carbon capture ratio (CCR), carbon dioxide purity (CP), H2 recovery (HR) and/or hydrogen purity (HP). A high CCR and high CP can be achieved, but generally at the expense of a certain CAPEX (number of SEWGS columns) and OPEX (steam consumption).
WO 2010/059055 (EP 2362848) discloses a water gas shift process with a reaction stage, wherein the reaction stage comprises (a) providing a gas mixture comprising CO, H2O and an acid gas component to a reactor containing an adsorbent, and (b) subjecting the gas mixture to water gas shift reaction conditions to perform the water gas shift reaction. The adsorbent used in WO 2010/059055 comprises an alkali promoted hydrotalcite material, and the acid gas component comprises H2S.
EP 2739373 discloses a water gas shift (WGS) process for the removal of acidic gases by adsorption, and relies on the selective desorption of adsorbed acidic gases from adsorbents that are suitably used in such processes. In such processes using basic adsorbents, acidic gaseous components such as carbon dioxide and hydrogen sulphide end up in the same product (or effluent) stream, which makes reuse or purification of these streams difficult. EP 2739373 introduced a stepwise and selective removal of gaseous acidic species for adsorbents used for producing desirable especially hydrogen-containing-gas mixtures by conducting a purging stage in two steps, thereby obtaining two different product gases. In this way an impurity (H2S) can be removed, such that the CO2 purity (CP) in the final product gas is increased.
WO 2013/122467 discloses that the high-pressure steam supply in a hydrogen production process can be made more efficient by a water gas shift process which comprises, in alternating sequence (i) a reaction stage wherein a feed gas comprising CO and H2O is fed into a water gas shift reactor containing a sorbent material capable of adsorbing H2O and CO2 and wherein a product gas issuing from the reactor is collected, (ii) a regeneration stage wherein CO2 is removed from the reactor, (iii) a loading stage, wherein H2O is fed into the reactor, wherein said feed gas mixture has a molar ratio of H2O to CO below 1.2, and the loading stage is performed at a lower pressure than the pressure of the reaction stage.
Boon et al. (Chemical Engineering Science 122, 2015, 219-231) published a research article on high-temperature pressure swing adsorption cycle design for sorption-enhanced water gas shift. The article describes a SEWGS process which combines the water-gas shift reaction with in situ adsorption of CO2 on potassium-promoted hydrotalcite and thereby allows production of hot, high-pressure H2 from syngas in a single unit operation. In this study, SEWGS is run as a cyclic process that comprises high-pressure adsorption and rinse stages, combined with pressure equalisation steps and purge at low pressure. The authors have shown that during the cycle, steam adsorbs in the rinse step and desorbs during the subsequent reduction in pressure, thereby improving the CO2 purity in the column and enhancing the efficiency of the rinse stage. Numerical simulations showed that the carbon capture ratio depends mainly on the purge steam to carbon feed ratio, whereas the CO2 product purity depends mainly on the rinse steam to carbon feed ratio. Optimisation of the process parameters provided a SEWGS cycle that consumes significantly less steam than cycle designs known until then, and significantly less energy than CO2 separation technologies known until then. The present invention relates to a SEWGS cycle with reduced CAPEX and/or OPEX for a given performance in terms of CCR and CP.
There nevertheless remains a general need to further improve the existing SEWGS processes in terms of operational economy, sustainable use of resources and overall cost. For example, a specific challenge remains to simultaneously achieve both a high CCR and a high CP in SEWGS processes at substantially lower steam use, while providing an H2 product stream that is suitable for further industrial, chemical processes. The process according to the invention provides in this need.
Accordingly, the invention provides a sorption-enhanced water-gas shift (SEWGS) process for the formation of a CO2 product stream and an H2 product stream, wherein the process comprises:
The present inventors have found that both a high carbon capture ratio (CCR) and carbon dioxide purity (CP) in SEWGS processes can be achieved with significant reduced amount of steam than conventional processes, while providing an H2 product stream of high purity that is suitable for further industrial, chemical processes, by employing a pre-blowdown step, which is employed before a blowdown step. During the pre-blowdown step, the pressure in the SEWGS reactor is reduced to a total pressure in the range of 5 to 50 bar.
The process according to the invention hence incorporates a pre-blowdown step in an SEWGS process, which represents an intermediate step enabling the collection of impurities. The pre-blowdown step also allows for a simultaneous improvement of the carbon capture ratio (CCR) and the carbon dioxide purity (CP) in the overall SEWGS process at reduced steam usage. The pre-blowdown step differs from a pressure equalisation step in that the released gas is not kept in the pressure equalisation cycle, but instead the released gas is collected separately.
The present invention will be discussed in more detail below, with reference to the attached drawings, in which:
The invention provides a sorption-enhanced water-gas shift (SEWGS) process for the formation of an intermediate stream, a CO2 product stream and an H2 product stream. The inventors have found that an optimization of the regeneration of the SEWGS reactor, after the water-gas shift reaction has been performed, enables the formation of a substantially pure CO2 product stream and a substantially pure H2 product stream. This optimization step resides in a pre-blowndown step, wherein the pressure is reduced to close to the regeneration pressure. The off gas released from the reactor during the pre-blowdown step is collected separately from the CO2 product stream released from the reactor during the blowdown step.
The reaction pressure is the pressure during step (a); the pre-blowdown pressure is the pressure at which the pre-blowdown step begins; the blowdown pressure is the pressure at which the pre-blowdown step ends and the blowdown step begins; and the regeneration pressure is the pressure at the end of the blowdown step.
More specifically, the process according to the invention comprises:
The present inventors have found that both a high carbon capture ratio (CCR) and carbon dioxide purity (CP) in SEWGS processes can be achieved, while providing an H2 product stream that is suitable for further industrial, chemical processes, by employing a pre-blowdown step, which is employed before a blowdown step. During the pre-blowdown step, the pressure in the SEWGS reactor is reduced to establish a blowdown pressure in the range of 0.5 to 1.5 times the partial pressure of CO and CO2 in the feed gas of step (a). The pre-blowdown step is thus characterised by a decreased initial blowdown pressure as compared to the blowdown pressure of the actual blowdown step, wherein the pressure in the SEWGS reactor is reduced to the regeneration pressure which is between 1 and 5 bar.
In step (a), the water-gas shift reaction takes place. A feed gas comprising COx, wherein x=1-2, and H2O is fed into a SEWGS reactor containing a catalyst and sorbent material capable of adsorbing CO2. The CO2 molecules formed during the water-gas shift reaction and/or present in the feed are sorbed onto the sorbent material, thereby forming a sorbent material loaded with CO2. Typically, at the beginning of step (a), the sorbent material contains sorbed water molecules. During step (a) water molecules are desorbed and CO2 molecules are adsorbed. As such, CO2 is removed from the product mixture of the water-gas shift reaction, thereby pushing the equilibrium towards the product side. The off gas of the reactor during step (a) will thus contain H2 and desorbed molecules, typically steam.
Such sorption-enhanced water-gas shift reactions are known in the art. Step (a) can be performed in any way known in the art. The skilled person is capable of selecting an appropriate sorbent material and catalyst, as well as appropriate conditions for performing the water-gas shift reaction. In a preferred embodiment, the reaction of step (a) is performed at a reaction pressure in the range of 15-50 bar, preferably in the range of 20-30 bar, most preferably in the range of 22-25 bar.
The feed comprises COx, wherein x=1-2, and H2O, and typically further comprises H2. COx denotes CO, CO2 or mixtures thereof, and may also be referred to as “carbon oxide”, with CO and CO2 being the two carbon oxide species, or as “CO and/or CO2”. The value of x denotes the number of oxygen atoms present per carbon atom in the carbon oxide fraction (i.e. CO+CO2) of the feedstock, irrespective of any further oxygen and/or carbon atoms that may be present in the feedstock. Thus, x is in the range of 1-2, wherein x=1 indicates pure CO and x=2 indicates pure CO2. An intermediate value for x indicates that a mixture of CO and CO2 is present in the feedstock, which can readily be determined by the skilled person. As example, when x=1.9, 1.9 oxygen atoms are present per carbon atom, meaning that the molar ratio of CO:CO2 is 1:9. Likewise, when x=1.5, the CO:CO2 molar ratio is 1:1.
The process according to the invention operates efficiently using a feedstock wherein x is any value in the range 1-2. In one embodiment, the feedstock contains CO, or in other words x<2, i.e. 1≤x<2. In one embodiment, CO2 may be the major carbon oxide species and x is close to 2, e.g. x=1.3-2, preferably x=1.4-1.8. In an alternative embodiment, CO may be the major carbon oxide species and x is close to 1, e.g. x=1-1.8, preferably x=1-1.5, more preferably x=1-1.2, or even x=about 1.
Alternatively worded, the feedstock contains 0-10 mol % CO and 0-80 mol % CO2, wherein the total content of COx in the feedstock is at least 2 mol %, preferably in the range of 2-80 mol %, more preferably 2-60 mol %. Preferably, the feedstock contains 2-8 mol % CO and 0-30 mol % CO2, wherein the total content of COx in the feedstock is preferably in the range of 2-20 mol %, more preferably 3-10 mol %.
A certain amount of CO2 may thus be present in the feed. Any H2 and CO2 is not converted in the process according to the invention, but ends up in respectively the H2 product stream or the CO2 product stream. The feed may also contain further gaseous components which are inert in the reaction according to the invention, such as inert gases (e.g. N2, Ar, CH4 and larger hydrocarbons, such as up to C4) and contaminants arising from the industrial process, such as syngas originating from reforming or gasification of fossil or biogenic feedstocks, from which the feed originates (e.g. H2S, NOx, etc.). Important for the operation of the process, especially for the pre-blowdown step (c), is the partial pressure of the sum of CO and CO2 (i.e. of COx) in the feed. Since all CO will be converted to CO2 during step (a), this represents the amount of CO2 present in the system and to be collected during the regeneration steps (b)-(e). The inventors found that the performance of the process, in terms of CCR and CP, was optimal when the blowdown pressure was chosen to be close to the amount of CO2 present in the system, i.e. close to the partial pressure of COx in the feed of step (a). Typically, the partial pressure of COx in the feed is in the range of 1-50 bar, preferably 2-20 bar, more preferably 5-15 bar, most preferably about 10 bar. As such, the majority of the CO2 will still be in the reactor at the beginning of blowdown step (d) and collected in the CO2 product stream, while other components and impurities are largely removed from the system, mainly in the pre-blowdown off-gas.
The off gas of the reaction step (a) forms the H2 product stream, and contains H2 and desorbed molecules, and optionally any inert gases that are present in the feed and defined elsewhere. The H2 product stream may be subjected to further purification, such as removal of the desorbed molecules. For example, a condensation step could advantageously remove desorbed water molecules.
At some point, preferably before break-through of CO2, the reactor is subjected to a regeneration sequence, wherein it is regenerated in order to be subjected to step (a) again. It is thus preferred that the process according to the invention is operated in cyclic mode. The regeneration sequence involves steps (b)-(e). The regeneration may be referred to as a pressure swing adsorption (PSA).
Rinse step (b) is the first step of the regeneration sequence, wherein steam is fed to the SEWGS reactor to establish a pressure between 5 and 50 bar. At these conditions, water molecules are adsorbed onto the sorbent, while CO2 molecules are desorbed, releasing CO2 into the gas phase of the reactor. At the beginning of step (b), the gaseous volume of the reactor will mainly contain H2 and possible non-sorbed CO2 molecules.
At the very beginning of step (b), the off-gas may contain predominantly H2, and may optionally be collected together with the H2 product stream obtained during step (a). The skilled person is able to determine when the stop collecting the H2 product stream, and switch to separate collection of the off-gas. In a preferred embodiment, the switch to separate off-gas collection is made at the start of step (b), which is particularly advantageous in case the reactor is switched from step (a) to step (b) close to break-through of CO2.
Preferably, the rinse of step (b) is performed at substantially the same pressure as the reaction of step (a), although a slight pressure change (typically a slight increase) may occur in view of the introduction of steam. The pressure during step (b) typically is in the range of 20-50 bar, preferably in the range of 22-28 bar, more preferably in the range of 24-26 bar. The amount of steam that is fed into the SEWGS reactor during rinse step (b) can be lowered compared to conventional processes not including a pre-blowdown step. The amount of steam may be in the range of 0.01-0.5 mol %, preferably 0.02-0.2 mol % or even as low as 0.02-0.1 mol %, based on the amount of COx feed during step (a). The inventors have obtained optimal results in terms of CO2 purity and carbon capture rate with such low amounts of steam.
The process according to the invention incorporates a pre-blowdown step in a SEWGS process, which represents an intermediate step enabling the collection of impurities before the actual blowdown step. The pre-blowdown step thereby also allows for a simultaneous improvement of the carbon capture ratio (CCR; i.e. the extent of incoming carbon atoms that are captured as CO2 in the CO2 product stream) and the carbon dioxide purity (CP) in the CO2 product stream.
During the pre-blowdown step, the pressure within the reactor is lowered to establish a blowdown pressure in the range of 0.5 to 1.5 times the partial pressure of COx in the feed gas of step (a). The actual pressure reduction achieved in the pre-blowdown step may vary depending on the starting pressure after the rinse and optional depressurizing steps, and the partial pressure of COx in the feed gas. For example, the pressure may be reduced by 1-25 bar, preferably by 2-8 bar, more preferably by 3-5 bar. In view of this pressure reduction, the actual blowdown step starts at a lower pressure compared to conventional regeneration sequences of a water-gas shift reactor. The pre-blowdown step differs from a depressurization step in the context of pressure equalisation in that the released gas is not kept in the pressure equalisation cycle, but instead is collected separately, as a pre-blowdown off-gas. The pre-blowdown off-gas may contain a combination of some remaining H2 still present in the reactor, non-adsorbed H2O, desorbed CO2 and any further component (e.g. inert gases) that may be present in the feed and/or the steam rinse gas of step (b). Thus, the pre-blowdown off-gas is lean in CO2 but rich in energy.
A further advantage over existing SEWGS processes is that the incorporation of the pre-blowdown step does not require any additional rinse steam and also does not require any additional pressure equalisation steps, as the actual blowdown step starts at a lower pressure. The pre-blowdown step is hence similar to the blowdown step in that gas in the SEWGS reactor is released by lowering the pressure, without using a purge gas. An important difference is that the gas released in the pre-blowdown step and the gas released in the blowdown step are collected separately. The pre-blowdown step has the advantage that the product gas from the blowdown step is of better quality, i.e. has a higher CP, and additionally provides increased control of the exact pressure at which the blowdown step is performed. In view of the pre-blowdown step, the process according to the invention does not need to employ multiple purging steps, but instead uses a pre-blowdown step and the actual blowdown step, which is technically simpler to realise, and having the additional advantage of increased control of the starting pressure of the blowdown step. In one embodiment, the pre-blowdown and blowdown off-gases are collected at the same side of the column, for example at the top side. In other words, the pre-blowdown and blowdown steps are preferably performed co-currently, preferably in the direction of the feed. As such, the separate handling of both gases is conveniently done by the simple switching of a valve from a first position configured to collect pre-blowdown off-gas to a second position configured to collect blowdown off-gas. As such, both off-gases can efficiently be led to the appropriate further handling thereof, as further discussed below.
Typically, the pre-blowdown step is preceded by one or more depressurizing steps. Those are typically paired with pressurizing steps which may occur after the purge step, as part of one or more pressure equalizing steps. The skilled person is familiar with pressure equalizing steps in the context of a pressure swing adsorption regeneration sequence. Advantageously, the carbon purity can be enhanced by introducing pressure equalisation steps which effect depressurisation of the SEWGS reactor directly after the rinse step (b) which leads to a decreased initial blowdown pressure. Generally, a high blowdown pressure, i.e. the pressure at which the blowdown step and the collection of the CO2 product stream starts, causes a relatively larger amount of impurities in the CO2 product stream, which hamper proper capture of the CO2. Furthermore, any H2 molecule that ends up in the CO2 product stream reduces the H2 yield of the process.
During the pre-blowdown step, the pressure within the reactor is reduced, typically by 2-8 bar, preferably by 3-5 bar. The pre-blowdown step typically starts at a pressure in the range of 5-20 bar, preferably in the range of 8-16 bar, at which pressure gas is released from the reactor and collected separately as a pre-blowdown off-gas. During pre-blowdown, no gas enters the reactor and all release of gas is caused by the pressure release. At a certain pressure, the blowdown pressure, the off-gas collection is switched and the CO2 product stream is collected. This event marks the switch from the pre-blowdown step to the blowdown step. The blowdown pressure is typically in the range of 0.5-1.5 times the partial pressure of COx in the feed gas of step (a), preferably in the range of 0.8-1.2 times the partial pressure of COx in the feed gas. It is especially preferred that the blowdown pressure is about equal to the partial pressure of COx in the feed gas. Thus, in case the feed gas of step (a) would contain 2 bar of CO and 2 bar of CO2, it is preferred that the blowdown pressure, i.e. the pressure in the reactor at which the collection of the CO2 product stream starts, is about 4 bar. Additionally or alternatively, the blowdown pressure is defined in absolute terms. In one embodiment, the blowdown pressure is in the range of 2-10 bar, preferably 3-7 bar, most preferably about 4 bar.
Lower blowdown pressures lead to an even more pure CO2 product stream, but also to an increased release of CO2 into the pre-blowdown off-gas and thus in a lowered carbon capture ratio. Higher blowdown pressures lead to less CO2 released into the pre-blowdown off-gas and thus in an increased carbon capture ratio, but also to reduced purity of the CO2 product stream. The inventors found that the blowdown pressures presented here provide the optimal balance, such that the SEWGS process according to the invention provides an unprecedented combination of CO2 product stream purity and carbon capture ratios at a given steam usage.
The off gas of the pre-blowdown step may be used as deemed fit. As this gas contains a combination of gaseous molecules that are useful within the process, it is preferred that the pre-blowdown off gas is subjected to reaction step (a). This may be effected by combining the pre-blowdown off gas with the feed of step (a), and subjecting the combined mixture to the reactor in step (a), of by separately introducing the feed of step (a) and the pre-blowdown off gas to the reactor of step (a). As such, H2 molecules present in the pre-blowdown off gas will end up in the H2 product stream and CO2 molecules present in the pre-blowdown off gas will end up in the CO2 product stream. Preferably, H2O molecules are removed from the pre-blowdown off gas before it is subjected to step (a), typically by condensation, to lower the volume that is to be subjected to step (a). Since the pre-blowdown off gas contains gases from a pressure drop of 2-8 bar, of which H2O molecules may further have been removed, it is a relatively small stream, which does not reduce the capacity of the reactor in step (a) too much.
In an alternative embodiment, the pre-blowdown off gas is separately collected as tail gas, e.g. as a product stream of the process, and used as deemed fit. Process integration options can preferably make use of the particular composition of this stream. For example, it may be combusted to generate heat needed for the process according to the invention. The presence of steam in this stream may be beneficial for control of the NOx emissions as shown by Chiesa P, Lozza G & Mazzocchi L (2005), Using hydrogen as gas turbine fuel, J. Eng. Gas Turbines Power 127(1), 73-80; and Göke S, Furi M, Bourque G, Bobusch B, Göckeler K, Krüger O et al. (2013), Influence of steam dilution on the combustion of natural gas and hydrogen in premixed and rich-quench-lean combustors, Fuel processing technology 107, 14-22. A further advantage is that steam dilution of H2 also allows to lower the reactivity of hydrogen, because already a relatively low steam content prevents flashback, and thus reduces the risk of explosion.
In case the pre-blowdown off gas is recompressed and recycled to step (a), the presence of CO2 in the pre-blowdown off gas does not lead to a reduction in carbon capture ratio, since the CO2 molecules are not collected but recycled and will thus largely end up in the CO2 product stream anyway. Thus, a slightly lower blowdown pressure, preferably in the range of 2-4 bar, preferably about 3 bar, can be used in order to increase the purity of the CO2 product stream. On the other hand, in case the pre-blowdown off gas is collected as tail gas, it is preferred that it contains as little as possible CO2, and thus a somewhat higher blowdown pressure, preferably in the range of 3-8 bar, preferably about 5 bar, is preferred in order to increase the carbon capture ratio of the process according to the invention. Alternatively worded, the blowdown pressure is in the range of 0.5-1.25, preferably 0.5-1, times the partial pressure of CO and CO2 in the feed gas of step (a) when the pre-blowdown off gas is recompressed and recycled to step (a), and the blowdown pressure is in the range of 0.75-1.5, preferably 1-1.5, times the partial pressure of CO and CO2 in the feed gas of step (a) when the pre-blowdown off gas is collected as tail gas.
Step (d) of the process according to the invention involves the actual blowdown step, wherein the CO2 product stream is collected. In order to facilitate carbon capture processes, the purity of this stream should be as high as possible, and the intermediate pre-blowdown step enables higher purities of the stream. The blowdown step of the present invention differs from conventional blowdown steps in that it starts at a somewhat reduced pressure, in view of the pressure released from the reactor during the pre-blowdown step (c).
Thus, the blowdown pressure, at which the blowdown step starts, is typically in the range of 2-10 bar, preferably 3-7 bar, most preferably about 4 bar. During the blowdown step, the pressure is further reduced to the regeneration pressure, which is in the range of 1-5 bar, preferably in the range of 1.5-3 bar. The pressure drop during the blowdown step is preferably in the range of 0.2-7.5 bar, more preferably in the range of 0.5-5 bar, most preferably about 1 bar. During blowdown, gaseous CO2 molecules present in the reactor are released into CO2 product stream. Furthermore, the release of any remaining adsorbed CO2 molecule from the sorbent is promoted in view of the drop in CO2 pressure within the reactor. As such, CO2 is released from the reactor to a large extent, and the CO2 product stream is substantially pure. When desired, a water condensation step can be employed in order to increase the CO2 concentration of the CO2 product stream. This is common practice for carbon capture and storage processes.
The process continues with a purge step, wherein steam is fed to the reactor. The introduction of steam leads to a lowering of the partial pressure of CO2 within the reactor and thus to the release of further CO2 molecules from the sorbent. During the purge step, pressure is typically not built up in the reactor, but the reactor remains at the regeneration pressure and an off-gas is collected. Typically, the off-gas of the purge step is collected as part of the CO2 product stream. It contains mainly CO2 and some non-adsorbed H2O molecules (steam).
At the end of the purge step, the sorbent is loaded with H2O molecules, and is ready for another reaction step. In a further preferred embodiment, the process according to the invention further comprises one or more repressurisation steps, which are performed after the purge step (e) and in which the pressure in the reactor is raised to the pressure of reaction step (a). If needed, the pressure of the feed or high-pressure product ensures that the reactor is pressurized to the desired pressure in order to perform step (a). Such repressurisation steps preferably are coupled to the depressurisation steps performed before the pre-blowdown step (c), as part of one or more pressure equalisation steps.
In a preferred embodiment, the process according to the invention is run as a cycle. When run as a cycle, the reactor at the end of the purge step (e) and preferably after being repressurised, is used in reaction step (a), wherein a feed gas comprising CO and H2O is fed into the reactor. In a further embodiment, when the process according to the invention is run as a cycle, at least two SEWGS reactors each undergoing the cycle are coupled. Preferably, at least 4 SEWGS reactors are coupled, such as 2-20 reactors, preferably 4-10 reactors. As such, one reactor is used for reaction step (a) while a second reaction is undergoing the regeneration sequence, which enables a continuous feed of the feed comprising CO and H2. It is further preferred that one SEWGS reactor requiring depressurisation is coupled to another SEWGS reactor requiring repressurisation, thereby allowing one or more pressure equalisation steps which effect depressurisation of the first SEWGS reactor after the rinse step (b), and one or more respective pressure equalisation steps which effect repressurisation of the second SEWGS reactor directly after the purge step (e). In a more preferred embodiment, when the process according to the invention is run as a cycle, a multitude of SEWGS reactors each undergoing the cycle are coupled, wherein each of the multiple first SEWGS reactors requiring depressurisation is coupled to one of the multiple second SEWGS reactors in another step of the cycle requiring repressurisation, thereby allowing one or more pressure equalisation steps which effect depressurisation of the multiple first SEWGS reactors after the rinse step (b), and one or more respective pressure equalisation steps which effect repressurisation of the multiple second SEWGS reactors directly after the purge step (e).
In a preferred embodiment of the process according to the invention, the reactor undergoes the reaction step (a), the rinse step (b), the pre-blowdown step (c), the blowdown step (d), and the purge step (e), and optionally one or more intermediate pressure equalisation steps, in sequential order, preferably without substantial modification of the reactor by intermediate steps.
Reactors suitable for performing a SEWGS reaction are known in the art, and any such reactor may be employed for the process according to the invention. Typically, such a reactor is in the form of a column containing the sorbent material and catalyst, which may be present as fixed bed or fluidized bed. Suitable catalyst and sorbent materials are also known in the art, and any such material may be used in the context of the present invention.
The inventive idea of the present invention can also be employed in a process for the separation of a CO2 product stream from an inert gas product stream. Since water gas shift reactivity is not essential for the process according to this embodiment, the process is typically carried out in an adsorber (or adsorption column), which comprises a sorbent material capable of adsorbing CO2. Step (a) does not involve a reaction but only an adsorption and is thus referred to as an adsorption step. All other specifics, including preferred embodiments, as defined above for reaction step (a) equally apply to adsorption step (a). Likewise, all specifics for steps (b)-(e), including preferred embodiments, as defined above equally apply to the respective steps of the process according to the present embodiment.
The process according to this embodiment comprises:
The adsorption according to the present embodiment utilizes steam as working fluid. The feedstock of the process according to this embodiment is a gaseous mixture comprising CO2 and one or more inert gases. Herein, inert gases refers to gases that are not adsorbed by the sorbent, and thus exclude CO2 and H2O. CO may be part of the inert gases. If this is the case, it has an influence on the blowdown pressure established in step (c), as defined above. The one or more inert gases are typically selected from CO, H2, N2, Ar, C1-4 hydrocarbons, H2S and NOx. Most preferably, the inert gases comprise at least H2.
The isotherm SEWGS model developed by Boon et al. (Boon, J., Cobden, P. D., Van Dijk, H. A. J., Hoogland, C., van Selow, E. V., & van Sint Annaland, M. (2014), Isotherm model for high-temperature, high-pressure adsorption of CO2 and H2O on K-promoted hydrotalcite, Chemical Engineering Journal, 248, 406-414.) was used to describe the transport phenomena in the packed-bed column and adsorption of CO2 as H2O (Tables 1 and 2). The double adsorption isotherms for CO2 and H2O in Boon's model consisted of both surface as nanopores contributions. However, the sorption mechanism proposed by Coenen et al. 2017 (Coenen, K., Gallucci, F., Pio, G., Cobden, P., van Dijk, E., Hensen, E. & van Sint Annaland, M. (2017), On the influence of steam on the CO2 chemisorption capacity of a hydrotalcite-based adsorbent for SEWGS applications, Chemical Engineering Journal, 314, 554-569) also predicts that a competitive site contributes to the adsorption of CO2. In this study, the competitive site has been incorporated into the adsorption isotherms for both CO2 and H2O. Furthermore, only the adsorption of CO2 and H2O has been considered in this work. Any other gas species in the syngas mixture are not considered to be adsorbed by K-HTC.
Boundary conditions: The pressure was defined at the outlet of the column while the feed flowrate is defined at the inlet. The equations were discretized on a uniform grid in the spatial term. To prevent numerical shock problems, a second order flux delimited Barton's scheme for the convective terms was implemented in the code (Centrella, J. & Wilson, J. R. (1984), Planar numerical cosmology II—The difference equations and numerical tests, The Astrophysical Journal Supplement Series, 54, 229-249; Goldschmidt, M. J. V., Kuipers, J. A. M., & van Swaaij, W. P. M. (2001), Hydrodynamic modelling of dense gas-fluidised beds using the kinetic theory of granular flow: effect of coefficient of restitution on bed dynamics, Chemical Engineering Science, 56(2), 571-578; Boon, J., Cobden, P. D., Van Dijk, H. A. J., Hoogland, C., van Selow, E. V., & van Sint Annaland, M. (2014), Isotherm model for high-temperature, high-pressure adsorption of CO2 and H2O on K-promoted hydrotalcite, Chemical Engineering Journal, 248, 406-414.). For the dispersion terms a second order implicit central differencing scheme applied. The source terms were semi-implicit linearized. Dankwert's boundary conditions applied for the mass and heat balance.
Integration scheme: The now time-dependent ODEs were solved with an Euler forward scheme with time step adaption. Adaptation of the time step occurs in three cases. Firstly, when the maximum number of iterations occurred to obtain the lowest error. Secondly, if large changes occur between the initial steady-state solution and the current solution. Large changes are defined as the differences between these two states. Thirdly, if the Courant-Friederich-Lewy (CFL) condition, C, becomes higher than 0.5, the timestep was adjusted to meet C<0.5. The CFL condition is calculated according to C=u dt/dz in which dt is the timestep, dz the spatial stepsize, and u the velocity
Cyclic simulations: several different cycles were simulated. In the following sections the specific processing parameters and boundary conditions are given. All cycles were simulated in time as an extension of the single column model. Any connecting step in a cycle were temporarily stored in files. As the SEWGS process is a cyclic process, the simulations continues for several cycles until a cyclic steady state is reached. This state is reached when the performance indicators CCR and CP do not change more than 5%. The number of cycles that needs to be simulated depends on the applied conditions for the column. Typically, a minimum of 15 cycles was required. Data interpretation: For all models a set of performance indicators were determined. For the SEWGS process in general these indicators are the carbon capture and recovery ratio and the CO2 purity. The cycle performance indicated is indicated by the productivity, steam consumption, CO conversion, CO2 adsorption ratio. For all cases yi and Fmol are the integrals over time in given step. The integrals are approximated by the trapezoidal rule.
A process consisting of adsorption, rinse (with S/C=0.05), 3 pressure equalisations, pre-blowdown, blowdown, purge (with S/C=1.25) and repressurisation at cyclic steady-state was simulated. The accompanying cycle design corresponds to a single train system of 7 columns. The feed composition is shown in the table below:
The total feed flowrate is 3.42 kmol/h. In the simulations, the blowdown pressure, which is established at the end of the pre-blowdown phase, is set at 6 bar (Example 1A), 4 bar (Example 1B) or 6 bar (Example 1C), with a pre-blowdown pressure resulting from the pressure equalisations at 7.8 bar. The result of this variation and its effect on the carbon capture ratio (CCR) and the CO2 purity (CP) is shown in
Simulations confirmed that the same performance in terms of CCR and CP can be reached using a cycle design without a pre-blowdown step, albeit at a significantly higher steam consumption (OpEx) and a higher number of columns and trains (CapEx). Compared to the pre-blowdown cycle at a pre-blow-down pressure of 4 bar (Example 1B), achieving a CO2 purity of 97% and Carbon Capture Rate of 81% with 7 columns in a single train system and a total steam consumption of 1.25 S/C, a cycle design without pre-blowdown would require a steam consumption of 1.4 S/C and the double amount of columns. Therefore, a comparable performance of requires 12% higher steam consumption and 100% increase in CAPEX.
The same composition as Example 1 was simulated but with the pre-blowdown step being introduced into a system that is processing half the flowrate, i.e. 1.71 kmol/h. The blowdown pressure was varied between 2 and 8 bar. The result of this is shown in
An assessment was performed to see at what steam consumption, this optimum point can be achieved by a process design without pre-blowdown step and without an increase in CAPEX (i.e. same amount of columns). The results of this assessment is shown in
| Number | Date | Country | Kind |
|---|---|---|---|
| 20195765.1 | Sep 2020 | EP | regional |
| Filing Document | Filing Date | Country | Kind |
|---|---|---|---|
| PCT/EP2021/075133 | 9/13/2021 | WO |
