CN219431812U - System for exploiting and co-producing hydrogen by replacing natural gas hydrate - Google Patents
System for exploiting and co-producing hydrogen by replacing natural gas hydrate Download PDFInfo
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- CN219431812U CN219431812U CN202320222732.XU CN202320222732U CN219431812U CN 219431812 U CN219431812 U CN 219431812U CN 202320222732 U CN202320222732 U CN 202320222732U CN 219431812 U CN219431812 U CN 219431812U
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Abstract
The utility model discloses a system for exploiting and co-producing hydrogen by replacing natural gas hydrate, which comprises the following components: a gas injection unit comprising a gas injection unit for injecting CO 2 /H 2 First injection well bore of mixed gas and CO injection method 2 /N 2 A second injection wellbore of the gas mixture; the two are respectively connected with a deposition layer of the natural gas hydrate reservoir; a gas production unit comprising a gas production unit for CH 4 /H 2 First production well bore for mixed gas production and method for CH 4 /N 2 A second production wellbore for gas mixture production; the two are respectively connected with a deposition layer of the natural gas hydrate reservoir; a separation unit comprising a hydrogen separator with a first outlet for the CH to be recovered 4 /H 2 And separating the mixed gas to prepare hydrogen. The utility model uses CO 2 /N 2 Mixed gas of (2) and CO 2 /H 2 As an injection gas, to complete CO 2 Displacing CH out of the hydrate cage 4 At the same time, hydrogen is effectively prepared to realize CO 2 Is not discharged.
Description
Technical Field
The utility model relates to the technical field of natural gas exploitation, in particular to a system for exploiting and co-producing hydrogen by replacing natural gas hydrate.
Background
The hydrate displacement exploitation is to inject displacement gas into the hydrate layer in a certain temperature and pressure range, wherein the main displacement gas is CO 2 And (3) gas. The replacement gas enters the hydrate cage and replaces CH in the hydrate cage 4 The purpose of exploitation is achieved. CO 2 Gas displacement production of natural gas hydrates is possible, mainly because CO under the same pressure conditions 2 Hydrate ratio CH 4 The hydrate is more stable. Controlling the temperature and pressure to CO 2 Hydrate is stably present, CH 4 CO injection into the formation to the extent that the hydrate does not exist stably 2 ，CO 2 Can replace CH in the hydrate cage 4 。
For example, chinese patent application CN109736752A discloses a depressurization-assisted temperature control CO 2 A mining method for replacing natural gas hydrate relates to the field of natural gas hydrate mining, and comprises the following steps: firstly, carrying out depressurization exploitation, and injecting CO by using a gas injection well when the yield is too low 2 Replacement production of natural gas hydrate is carried out, so that the natural gas hydrate is produced and CO is injected 2 The gas is subjected to displacement reaction simultaneously, and the displacement is performedDuring the reaction, controlling the natural gas hydrate reservoir pressure within a carbon dioxide hydrate phase equilibrium pressure range corresponding to the natural gas hydrate reservoir temperature by controlling the outlet pressure of the injection pump, and controlling the injection CO when the temperature of the horizontal section of the gas injection well is close to the critical equilibrium temperature of the natural gas hydrate generation 2 The temperature of the gas hydrate realizes continuous proceeding of the displacement reaction in the stratum, prevents the displacement reaction from being unable to proceed due to the too low temperature, improves the displacement efficiency, and realizes the effective exploitation of the gas hydrate and CO 2 Is effectively buried in geology.
By pure CO 2 The displacement exploitation effect is not ideal, the reaction time is long, the displacement efficiency is low, and the reaction time is low due to the fact that the CH is not dissolved 4 Gradually generating CO on the surface of the hydrate 2 -CH 4 A mixed hydrate shell, which severely hinders CH 4 And CO 2 Further gas displacement of the molecules. And only CH in large hole during replacement 4 Can be CO 2 And (3) molecular substitution. Thus, increasing gas mass transfer during hydration-resolution increases CH 4 The recovery rate is critical. To solve CH 4 Small holes in the hydrate are replaced, the replacement rate is improved, and CO is injected into an underground reservoir in many ways 2 /N 2 CO 2 /H 2 。
In addition, long-distance transport of hydrogen is always a pain spot of the industry. In the hydrogen storage and transportation link of China, the current high-pressure long tube trailer is the main stream of the industry, but the mode has limited development prospect due to lower hydrogen storage efficiency. The ammonia gas prepared by using new energy as a raw material is likely to become an important carrier for large-scale transportation of hydrogen in the future, and the advantages of low cost of hydrogen conversion, sufficient ammonia gas supply and the like are considered, the volume hydrogen storage density in liquid ammonia hydrogen storage can be 1.7 times higher than that of liquid hydrogen, and meanwhile, the advantage is obvious compared with the mode of storing and transporting hydrogen in the current mainstream high-pressure long tube trailer.
Thus, there is a need for a natural gas hydrate displacement recovery system that achieves CO 2 Displacing CH out of the hydrate cage 4 Meanwhile, hydrogen can be effectively prepared and stored and transported in a liquid ammonia mode, and the whole system can realize CO 2 Is not discharged.
The information disclosed in this background section is only for enhancement of understanding of the general background of the utility model and should not be taken as an acknowledgement or any form of suggestion that this information forms the prior art already known to a person of ordinary skill in the art.
Disclosure of Invention
The utility model aims to provide a system for exploiting and CO-producing hydrogen by replacing natural gas hydrate, which uses CO 2 /N 2 Mixed gas of (2) and CO 2 /H 2 As an injection gas, to complete CO 2 Displacing CH out of the hydrate cage 4 Can effectively prepare hydrogen at the same time, and can realize CO in the whole process 2 Is not discharged.
Another object of the present utility model is to provide a system for the displacement exploitation of natural gas hydrates and the co-production of hydrogen, N obtained by separation in the system 2 And H 2 Liquid ammonia is obtained through synthesis, so that hydrogen is stored and transported in a liquid ammonia mode.
To achieve the above object, the present utility model provides a system for producing hydrogen by natural gas hydrate displacement and co-producing hydrogen, comprising: a gas injection unit comprising a gas injection unit for injecting CO 2 /H 2 First injection well bore of mixed gas and CO injection method 2 /N 2 A second injection wellbore of the gas mixture; the first injection shaft and the second injection shaft are respectively connected with a deposition layer of the natural gas hydrate reservoir; a gas production unit comprising a gas production unit for CH 4 /H 2 First production well bore for mixed gas production and method for CH 4 /N 2 A second production wellbore for gas mixture production; the first extraction shaft and the second extraction shaft are respectively connected with a deposition layer of the natural gas hydrate reservoir; a separation unit comprising a hydrogen separator with a first outlet for the CH to be recovered 4 /H 2 And separating the mixed gas to prepare hydrogen.
Further, in the above technical solution, the separation unit may further include a nitrogen separator, and a first outlet of the nitrogen separator is used for extracting CH 4 /N 2 Gas mixture separationNitrogen was prepared.
Further, in the above technical solution, the system of the present utility model may further include a liquid ammonia synthesis unit, where the liquid ammonia synthesis unit further includes: an ammonia synthesis tower that receives hydrogen from the hydrogen separator and nitrogen from the nitrogen separator and synthesizes ammonia; an ammonia liquefying tower connected with the ammonia synthesizing tower through a pipeline for preparing liquid ammonia; and a return pipeline is arranged between the ammonia liquefying tower and the ammonia synthesizing tower.
Furthermore, in the technical scheme, the liquid ammonia prepared by the method can be used as a carrier for hydrogen transportation.
Further, in the above technical scheme, when the prepared liquid ammonia is used, the liquid ammonia is decomposed into hydrogen and nitrogen through the ammonia decomposition tower.
Further, in the above technical solution, the hydrogen separator may further include a second outlet connected to the steam reforming unit, and configured to receive CH containing a small amount of hydrogen from the hydrogen separator 4 /H 2 Steam reforming and conversion of the mixture to CO 2 /H 2 And (3) mixing gas.
Further, in the above technical solution, the CO after steam reforming and conversion 2 /H 2 The gas mixture may be introduced into the first injection well bore.
Further, in the above technical solution, the nitrogen separator may further include a second outlet connected to the gas turbine for introducing a small amount of CH containing nitrogen from the nitrogen separator 4 /N 2 The mixed gas is combusted to generate electricity and CO is obtained 2 /N 2 And (3) mixing gas.
Further, in the above technical solution, the CO obtained by combustion 2 /N 2 The gas mixture may be introduced into a second injection wellbore.
Further, in the above technical solution, CO 2 /N 2 The mixing ratio of the mixed gas can be 3:7; CO 2 /H 2 The mixing ratio of the mixture may be 3:7.
Compared with the prior art, the utility model has the following beneficial effects:
1) The utility modelNovel use of CO 2 /N 2 Mixed gas of (2) and CO 2 /H 2 As an injection gas, to maintain the flow and displacement of gas in the reservoir; CH is obtained under the combined action of replacement and decompression 4 The replacement rate of the hydrate can be effectively improved; the hydrogen can reduce the partial pressure of methane in the free gas of the hydrate reservoir and excite the hydrate to decompose; the 'replacement' of gas injection and gas production can realize CH 4 Gas production and greenhouse gas CO 2 The geological storage of the hydrate can be maintained in the exploitation process, and the method has dual significance of environment and economy;
2) The liquid ammonia prepared by the method is used as a carrier for hydrogen transportation, namely, the hydrogen is stored and transported in the form of liquid ammonia. When the user needs to use hydrogen, the utility model can decompose the liquid ammonia into hydrogen and nitrogen through the ammonia decomposition tower. The transportation of green hydrogen is completed through the flow of hydrogen-ammonia-hydrogen;
3) The utility model separates the mixed gas CH by a separation unit 4 /N 2 (Low) and CH 4 /H 2 (low), the system is circulated and reinjected through natural gas power generation and steam reforming equipment respectively, so that CO of the system can be effectively ensured 2 Zero emission.
The foregoing description is only an overview of the present utility model, and it is to be understood that it is intended to provide a more clear understanding of the technical means of the present utility model and to enable the technical means to be carried out in accordance with the contents of the specification, while at the same time providing a more complete understanding of the above and other objects, features and advantages of the present utility model, and one or more preferred embodiments thereof are set forth below, together with the detailed description given below, along with the accompanying drawings.
Drawings
FIG. 1 is a schematic diagram of the system connection for the displacement production of natural gas hydrates and the co-production of hydrogen gas in accordance with the present utility model.
The main reference numerals illustrate:
1-first injection well bore, 2-second injection well bore, 3-first production well bore, 4-second production well bore, 5-CH 4 /N 2 Production gas transfer line, 6-nitrogen separator, 7-N 2 Transfer line, 8-CH 4 /H 2 Production gas conveying pipeline, 9-hydrogen separator and 10-H 2 Delivery line, 11-mixture delivery line, 12-ammonia synthesis column, 13-ammonia delivery line, 14-ammonia liquefaction column, 15-reflux line, 16-liquid ammonia output line, 17-liquid ammonia input line, 18-H 2 Output pipeline, 19-ammonia decomposing tower and 20-N 2 Output pipeline, 21-CH 4 /N 2 (low) transfer line, 22-gas turbine, 23-high temperature flue gas transfer line, 24-turbine, 25-CO 2 /N 2 Transfer line, 26-CH 4 /H 2 (low) transfer line, 27-steam inlet line, 28-reforming column, 29-reformed gas transfer line, 30-reforming column, 31-CO 2 /H 2 A transfer line.
Detailed Description
The following detailed description of embodiments of the utility model is, therefore, to be taken in conjunction with the accompanying drawings, and it is to be understood that the scope of the utility model is not limited to the specific embodiments.
Throughout the specification and claims, unless explicitly stated otherwise, the term "comprise" or variations thereof such as "comprises" or "comprising", etc. will be understood to include the stated element or component without excluding other elements or other components.
Spatially relative terms, such as "below," "beneath," "lower," "above," "upper," and the like, may be used herein for ease of description to describe one element's or feature's relationship to another element's or feature's in the figures. It will be understood that the spatially relative terms are intended to encompass different orientations of the article in use or operation in addition to the orientation depicted in the figures. For example, if the article in the figures is turned over, elements described as "below" or "beneath" other elements or features would then be oriented "above" the elements or features. Thus, the exemplary term "below" may encompass both a direction of below and a direction of above. The article may have other orientations (rotated 90 degrees or other orientations) and the spatially relative descriptors used herein interpreted accordingly.
The terms "first," "second," and the like herein are used for distinguishing between two different elements or regions and are not intended to limit a particular position or relative relationship. In other words, in some embodiments, the terms "first," "second," etc. may also be interchanged with one another.
In order to facilitate understanding of the roles played by the components and the connection relationships of the system of the present utility model, first, the process principles and procedures involved in the system are described:
the process adopts a depressurization mining mode to extract free gas in the natural gas hydrate deposit until the pressure of the natural gas hydrate deposit is reduced to the equilibrium pressure corresponding to the temperature of the hydrate deposit or 5-10% above the equilibrium pressure, and then the CO is injected into the natural gas hydrate deposit 2 /N 2 And CO 2 /H 2 Decomposing natural gas hydrate, and displacing to obtain CH 4 。
Specifically, CH released by displacement is produced by means of decompression mining 4 And the residual mixed gas N in the natural gas hydrate deposit 2 And H 2 Make up of a mixed gas CH 4 /N 2 And CH (CH) 4 /H 2 The method comprises the steps of carrying out a first treatment on the surface of the Will CH 4 /N 2 Separating to obtain N 2 And CH 4 /N 2 (low) mixed gas; will CH 4 /H 2 Separation to obtain H 2 And CH 4 /H 2 (low) mixed gas; will CH 4 /N 2 The (low) mixed gas is used for generating electricity by a gas turbine to obtain CO 2 /N 2 Is a mixed gas of (a) and (b); will CH 4 /H 2 The (low) mixed gas is subjected to steam reforming to obtain CO 2 /H 2 Is a mixed gas of (a) and (b); CO is processed by 2 Mixed gas of/N2 and CO 2 /H 2 The mixed gas of (2) is circularly injected into a natural gas hydrate deposit layer to continuously replace and mine natural gas hydrate; separating H 2 And N 2 NH is generated through synthesis reaction 3 The method comprises the steps of carrying out a first treatment on the surface of the To synthesize NH 3 Liquefying and then conveying; NH to be delivered to user 3 Decomposing to generate N 2 And H 2 。
As shown in figure 1 of the drawings,the utility model provides a system for exploiting and co-producing hydrogen by replacing natural gas hydrate by adopting the process, which at least comprises a gas injection unit, a gas production unit and a separation unit. Wherein the gas injection unit comprises a gas injection unit for injecting CO 2 /H 2 First injection shaft 1 for gas mixture and method for injecting CO 2 /N 2 A second injection wellbore 2 of the mixture; the first injection well bore 1 and the second injection well bore 2 are connected to a sedimentary layer of a natural gas hydrate reservoir 32, respectively. The gas production unit comprises a gas production unit for CH 4 /H 2 First production wellbore 3 for mixed gas production and method for CH 4 /N 2 A second production wellbore 4 for gas mixture production; the first production well bore 3 and the second production well bore 4 are connected to a sedimentary layer of the natural gas hydrate reservoir 32, respectively. The separation unit comprises a hydrogen separator 9, the first outlet of which is used for extracting said CH 4 /H 2 And separating the mixed gas to prepare hydrogen. The separation unit further comprises a nitrogen separator 6, the first outlet of the nitrogen separator 6 being for the CH to be extracted 4 /N 2 And (5) separating the mixed gas to prepare nitrogen.
During the first exploitation, the exploitation can be carried out in a depressurization mode, the pressure in the well is reduced to 5-10% of the corresponding equilibrium pressure or the pressure above the equilibrium pressure of the hydrate, and then CO is used 2 /N 2 Mixed gas of (2) and CO 2 /H 2 As an injection gas, the injection temperature of the mixture is not limited, and the injection pressure is controlled above the formation pressure to maintain the flow and displacement of the gas in the reservoir; CH is obtained under the combined action of replacement and decompression 4 Wherein in a larger hydrate cage, CO 2 Is prone to replace CH 4 While in smaller cages, N 2 Is prone to replace CH 4 . The replacement rate of the hydrate is improved. Wherein the hydrogen gas has the function of reducing the partial pressure of methane in the free gas of the hydrate reservoir and exciting the hydrate to decompose. Substitution mining can realize CH 4 Gas production and greenhouse gas CO 2 Geological sequestration of (i.e. CO implementing the present system) 2 Zero emission), and the hydrate is maintained to be stable in the exploitation process, thereby having dual significance of environment and economy.
Further toAs shown in fig. 1, the system of the present utility model further includes a liquid ammonia synthesis unit further including an ammonia synthesis column 12 and an ammonia fluidizing column 14. The ammonia synthesis tower 12 receives the hydrogen from the hydrogen separator 9 and the nitrogen from the nitrogen separator 6 and synthesizes ammonia; an ammonia liquefying column 14 is connected to the ammonia synthesizing column 12 through a line for producing liquid ammonia. A reflux line 15 is also provided between the ammonia liquefying tower 14 and the ammonia synthesizing tower 12. The liquid ammonia prepared by the method is used as a carrier for hydrogen transportation, namely, the hydrogen is stored and transported in the form of liquid ammonia. When the user needs to use hydrogen, the utility model can decompose the liquid ammonia into hydrogen and nitrogen through the ammonia decomposition tower 19 and pass through H 2 Output lines 18 and N 2 The output lines 20 output separately.
Specifically, the first injection well bore 1 and the second injection well bore 2 are in communication with a sedimentary layer of the natural gas hydrate reservoir 32, and the sedimentary layer of the natural gas hydrate reservoir 32 is connected to the first production well bore 3 and the second production well bore 4. The first production well bore 3 and the second production well bore 4 are respectively connected with CH 4 /H 2 Production gas transfer lines 8 and CH 4 /N 2 Production gas conveying pipeline 5 is connected with CH 4 /H 2 Production gas transfer lines 8 and CH 4 /N 2 The produced gas conveying pipeline 5 is respectively connected with the hydrogen separator 9 and the nitrogen separator 6, and the first outlets of the two separators are respectively connected with H 2 Transfer lines 10 and N 2 Transfer line 7 is connected to H 2 Transfer lines 10 and N 2 The transfer line 7 is connected with the mixed gas transfer line 11, the mixed gas transfer line 11 is connected with the first inlet of the ammonia synthesis tower 12, the ammonia synthesis tower 12 is connected with the ammonia transfer line 13, the ammonia transfer line 13 is connected with the ammonia fluidizing tower 14, the first outlet of the ammonia fluidizing tower 14 is connected with the reflux line 15, the reflux line 15 is connected with the second inlet of the ammonia synthesis tower 12, the second outlet of the ammonia fluidizing tower 14 is connected with the liquid ammonia output line 16, the liquid ammonia output line 16 is connected with the liquid ammonia input line 17, the liquid ammonia input line 17 is connected with the ammonia decomposing tower 19, the first outlet of the ammonia decomposing tower 19 is connected with H 2 An output line 18 is connected to a first outlet of the ammonia decomposing column 19 and N 2 The output line 19 is connected.
By the connection of the devices of the above system,the system of the present utility model injects CO into natural gas hydrate 2 /N 2 And CO 2 /H 2 Is decomposed and replaced into methane gas by depressurization of natural gas hydrate to obtain mixed gas CH 4 /N 2 And CH (CH) 4 /H 2 . Mixed gas CH 4 /N 2 And CH (CH) 4 /H 2 N with a molar fraction higher than 95% can be obtained after passing through the separation device 2 And H 2 . 95% of N obtained after separation 2 And H 2 Synthesizing to obtain NH 3 Synthesized NH 3 Liquid ammonia is obtained after liquefaction, namely H is finally obtained in the exploitation process 2 And N 2 High purity H 2 And N 2 Reacting to generate NH 3 ，NH 3 Can be conveniently transported to users through liquefaction, and can be decomposed to generate clean energy gas H at a destination 2 . The utility model can convey the liquid ammonia to the user side by various conveying modes, and when hydrogen is needed to be used, the liquid ammonia conveyed to the user side can be further decomposed into H 2 And N 2 . The transportation of green hydrogen is completed through the flow path of hydrogen-ammonia-hydrogen.
As further shown in fig. 1, the hydrogen separator 9 further comprises a second outlet connected to the steam reforming unit for CH containing a small amount of hydrogen from the hydrogen separator 9 4 /H 2 Steam reforming and conversion of the mixture to CO 2 /H 2 And (3) mixing gas. Further, the CO after steam reforming and conversion 2 /H 2 The mixed gas is introduced into the first injection shaft 1 to realize gas production and gas injection circulation. Specifically, the second outlet of the hydrogen separator 9 is connected to CH 4 /H 2 The (low) transfer line 26 being connected to CH 4 /H 2 The (low) transfer line 26 is connected to a first inlet of a reformer 28, the steam intake line 27 is connected to a second inlet of the reformer 28, the reformer 28 is connected to a reformed gas transfer line 29, the reformed gas transfer line 29 is connected to a reformer 30, and the reformer 30 is connected to CO 2 /H 2 Delivery line 31 is connected to CO 2 /H 2 A transfer line 31 is connected to the first injection well bore 1.
Further as shown in the figure1, the nitrogen separator 6 further comprises a second outlet, the second outlet of the nitrogen separator 6 being connected to a gas turbine 22 for CH containing a small amount of nitrogen from the nitrogen separator 6 4 /N 2 The mixed gas is combusted to generate electricity and CO is obtained 2 /N 2 And (3) mixing gas. Further, CO obtained by combustion 2 /N 2 The mixture is introduced into the second injection well bore 2. Specifically, the second outlet of the nitrogen separator 6 is connected to CH 4 /N 2 The (low) transfer line 21 being connected to CH 4 /N 2 The (low) transfer line 21 is connected to a gas turbine 22, the gas turbine 22 is connected to a high temperature flue gas transfer line 23, the high temperature flue gas transfer line 23 is connected to a turbine 24, the turbine 24 is connected to CO 2 /N 2 Delivery line 25 is connected to CO 2 /N 2 A transfer line 25 is connected to the second injection well bore 2.
The utility model produces the mixed gas CH 4 /N 2 And CH (CH) 4 /H 2 The N with the mole fraction higher than 95% is obtained after passing through the separation equipment (the nitrogen separator 6 and the hydrogen separator 9) 2 And H 2 (corresponding first outlet acquisition) and gas mixture CH 4 /N 2 (Low) and CH 4 /H 2 (low) (corresponding second outlet pickup). Mixed gas CH 4 /N 2 (Low) and CH 4 /H 2 The methane is converted from the natural gas through (low) power generation and steam reforming, and the natural gas power generation and reforming process can adopt any natural gas power generation and steam reforming hydrogen production process technology which is currently applied to industry. Obtaining CO 2 /N 2 And CO 2 /H 2 Is circulated and refilled. Preferably, but not by way of limitation, CO 2 /N 2 The mixing ratio of the mixed gas is 3:7; CO 2 /H 2 The mixing ratio of the mixed gas is 3:7; injected mixed gas CO 2 /N 2 And CO 2 /H 2 Is controlled below formation pressure to maintain gas flow and displacement in the reservoir. The system of the utility model can realize CO by recycling and reinjection 2 Is not discharged.
The foregoing descriptions of specific exemplary embodiments of the present utility model are presented for purposes of illustration and description. It is not intended to limit the utility model to the precise form disclosed, and obviously many modifications and variations are possible in light of the above teaching. The exemplary embodiments were chosen and described in order to explain the specific principles of the utility model and its practical application to thereby enable one skilled in the art to make and utilize the utility model in various exemplary embodiments and with various modifications as are suited to the particular use contemplated. Any simple modifications, equivalent variations and modifications of the above-described exemplary embodiments should fall within the scope of the present utility model.
Claims (8)
1. A system for displacement production of natural gas hydrates and co-production of hydrogen gas, comprising:
a gas injection unit comprising a gas injection unit for injecting CO 2 /H 2 First injection well bore of mixed gas and CO injection method 2 /N 2 A second injection wellbore of the gas mixture; the first injection shaft and the second injection shaft are respectively connected to a deposition layer of the natural gas hydrate reservoir;
a gas production unit comprising a gas production unit for CH 4 /H 2 First production well bore for mixed gas production and method for CH 4 /N 2 A second production wellbore for gas mixture production; the first extraction shaft and the second extraction shaft are respectively connected with a deposition layer of the natural gas hydrate reservoir;
a separation unit comprising a hydrogen separator, the hydrogen separator being provided with a first outlet.
2. The system for displacement production of natural gas hydrate and co-production of hydrogen of claim 1, wherein the separation unit further comprises a nitrogen separator having a first outlet.
3. The system for displacement production of natural gas hydrate and co-production of hydrogen according to claim 2, further comprising a liquid ammonia synthesis unit, the liquid ammonia synthesis unit further comprising:
the ammonia synthesis tower is respectively connected with the first outlet of the hydrogen separator and the first outlet of the nitrogen separator;
an ammonia liquefying tower connected to the ammonia synthesizing tower through a pipeline; and a return pipeline is arranged between the ammonia liquefying tower and the ammonia synthesizing tower.
4. A system for displacement production of natural gas hydrates and co-production of hydrogen as claimed in claim 3 wherein the liquid ammonia is a carrier for hydrogen transport.
5. The system for displacement recovery of natural gas hydrate and co-production of hydrogen of claim 1, wherein the hydrogen separator further comprises a second outlet, the second outlet of the hydrogen separator being connected to the steam reforming unit.
6. The system for producing and co-producing hydrogen of claim 5, wherein the steam reforming unit is coupled to the first injection wellbore.
7. The system for displacement production of natural gas hydrate and co-production of hydrogen of claim 2, wherein the nitrogen separator further comprises a second outlet, the second outlet of the nitrogen separator being coupled to the gas turbine.
8. The system for producing and co-operating with hydrogen gas from a natural gas hydrate displacement of claim 7, wherein the gas turbine is coupled to the second injection wellbore by a turbine.
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| CN202320222732.XU CN219431812U (en) | 2023-02-02 | 2023-02-02 | System for exploiting and co-producing hydrogen by replacing natural gas hydrate |
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| CN202320222732.XU CN219431812U (en) | 2023-02-02 | 2023-02-02 | System for exploiting and co-producing hydrogen by replacing natural gas hydrate |
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