CN114540089B - Natural gas desulfurization decarbonization agent and use method thereof - Google Patents
Natural gas desulfurization decarbonization agent and use method thereof Download PDFInfo
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- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
- C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
- C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
- C10L3/10—Working-up natural gas or synthetic natural gas
- C10L3/101—Removal of contaminants
- C10L3/102—Removal of contaminants of acid contaminants
- C10L3/103—Sulfur containing contaminants
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- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/34—Chemical or biological purification of waste gases
- B01D53/46—Removing components of defined structure
- B01D53/48—Sulfur compounds
- B01D53/52—Hydrogen sulfide
- B01D53/526—Mixtures of hydrogen sulfide and carbon dioxide
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- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/34—Chemical or biological purification of waste gases
- B01D53/46—Removing components of defined structure
- B01D53/62—Carbon oxides
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- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/34—Chemical or biological purification of waste gases
- B01D53/74—General processes for purification of waste gases; Apparatus or devices specially adapted therefor
- B01D53/77—Liquid phase processes
- B01D53/78—Liquid phase processes with gas-liquid contact
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- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/34—Chemical or biological purification of waste gases
- B01D53/96—Regeneration, reactivation or recycling of reactants
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- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
- C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
- C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
- C10L3/10—Working-up natural gas or synthetic natural gas
- C10L3/101—Removal of contaminants
- C10L3/102—Removal of contaminants of acid contaminants
- C10L3/104—Carbon dioxide
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- 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
- B01D2256/24—Hydrocarbons
- B01D2256/245—Methane
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- 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
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- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D2257/00—Components to be removed
- B01D2257/50—Carbon oxides
- B01D2257/504—Carbon dioxide
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- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
- C10L2290/00—Fuel preparation or upgrading, processes or apparatus therefore, comprising specific process steps or apparatus units
- C10L2290/54—Specific separation steps for separating fractions, components or impurities during preparation or upgrading of a fuel
- C10L2290/541—Absorption of impurities during preparation or upgrading of a fuel
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- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
- Y02P20/00—Technologies relating to chemical industry
- Y02P20/151—Reduction of greenhouse gas [GHG] emissions, e.g. CO2
Abstract
The invention belongs to the technical field of gas purification, and particularly discloses a natural gas desulfurization and decarbonization agent and a use method thereof. The invention discloses a novel natural gas desulfurization and decarbonization agent which is obtained by compounding liquid non-polymeric aminosilane and an organic solvent, wherein the natural gas is directly introduced into the normal-temperature natural gas desulfurization and decarbonization agent when in use, and the natural gas is absorbed for 30-45 min, so that purified natural gas is obtained. The natural gas desulfurization decarbonization agent has the characteristics of high reaction rate, high absorption capacity, low energy consumption and the like, and can selectively remove H in natural gas 2 S and CO 2 . The analysis operation is simple, the energy consumption is low, and the solvent loss is avoided.
Description
Technical Field
The invention relates to the technical field of gas purification, in particular to a natural gas desulfurization decarbonization agent and a use method thereof.
Background
Along with the optimization of the strategy of energy conservation and emission reduction in China, the specific gravity of natural gas in an energy structure is continuously increased, and the natural gas purification technology is widely focused.
When the natural gas contains acidic components, equipment and pipelines can be corroded in the processes of exploitation, treatment and storage and transportation, and the natural gas can pollute the environment and harm the health of users when used as fuel; when used as chemical raw materials, the catalyst can be poisoned, and the yield and quality of the product are affected. In addition, in the process of freezing and separating natural gas, if CO 2 Too high a content can form dry ice, block the pipeline and reduce the heat value of the pipeline, thereby causing production accidents. Thus, when the acid component content in natural gas exceeds the commodity gas quality is referred toWhen the standard or the pipe transportation is required, the standard or the pipe transportation is required to be removed to be within the allowable value by adopting a proper method. The natural gas contains acid mixture mainly containing H 2 S、CO 2 As well as water vapor and small amounts of hydrocarbons.
Removal of H from natural gas 2 S and CO 2 Is a common method of: wet, dry, membrane purification, and microbial desulfurization. The method using a solution or a solvent as an absorbent is called a wet method. Wet desulfurization and decarbonization are classified into physical solvent absorption method, chemical solvent absorption method, physical and chemical solvent absorption method, and the like. The dry desulfurization is a method for desulfurizing natural gas by using a solid adsorbent, namely, the surface of the solid desulfurizing agent is used for adsorbing acid gas or enabling the acid gas to react with certain components on the surface so as to achieve the purpose of desulfurization. Dry desulfurization includes molecular sieve methods and solid iron oxide methods, and dry methods are less used than wet methods.
Physical absorption method for wet desulfurization and decarbonization, capable of removing H in natural gas 2 S and CO 2 And organic acid (such as mercaptan), but the physical solvent has strong adsorption capacity to heavy hydrocarbon, so that the heat value of the purified gas is influenced, the later sulfur recovery quality is influenced, and the use and operation costs are high. Physical solvents used in industry include propylene carbonate, polyethylene glycol dimethyl ether, tributyl phosphate and N-methylpyrrolidone.
The chemical solvent absorption method is that on the basis of reversible reaction, an alkaline solvent and acid gas are utilized to react in raw material gas to generate a compound rich in acid gas, so that the acid gas is removed; the rich solution absorbing the acid gas can regenerate the alkaline solution at a higher temperature and a lower pressure to desorb the acid gas. Among them, the alcohol amine method is the most commonly used natural gas desulfurization and decarbonization method, including Monoethanolamine (MEA), diethanolamine (DEA), diglycolamine (DGA), diisopropanolamine (DIPA) and Methyldiethanolamine (MDEA). Water is generally used as the solvent for the alcohol amine process.
The Monoethanolamine (MEA) has the advantages of smaller molecular weight, good chemical stability, easy desorption of acid gas and the like in the natural gas wet desulfurization and decarbonization process. But its main disadvantages are MEA and SO 2 The reaction between them is irreversible, resulting in absorptionSubstantial loss of agent and accumulation of product. The MEA vapor pressure is higher and the evaporation loss is greater during the absorbent regeneration process.
Diethanolamine (DEA), which belongs to the secondary amine group, is similar in application and operation to MEA with the natural gas acid gas removal principle. However, DEA has a low reaction rate with sulfide, and the product is different, so that the reaction caused by solvent loss is relatively small and the corrosiveness is weak. Therefore, it is suitable for refinery gases and artificial gases having a high impurity content.
Methyl Diethanolamine (MDEA) belonging to tertiary amines has the advantages of good chemical stability, small flash evaporation regeneration loss of absorbent, weak corrosiveness, low regeneration energy consumption and the like in the natural gas desulfurization and decarbonization process. Acid mixed gas (CO) 2 、H 2 S), MDEA can be combined with H 2 S undergoes a rapid proton transfer reaction; and CO with 2 The reaction process is complex, the reaction rate is slow, and the selective H removal is realized 2 S, S. An aqueous solution of 30wt% MDEA is commonly used as a natural gas desulfurization absorber.
Physical-chemical solvent absorption processes purify natural gas, most typically by the sulphone amine process, the compounding of sulphone with Diisopropanolamine (DIPA) or Methyldiethanolamine (MDEA). It features high load of acidic gas and high purifying rate, and removing H 2 S and organic sulfur have the advantages of physical absorption and chemical absorption, but the cost of the compound absorbent is high.
The regeneration energy consumption of the absorbent and the loss of the absorbent are higher, the thermal oxidation stability is not ideal, the corrosion to equipment is serious, and the expansion application of the alcohol amine absorbent in the wet purification of natural gas is limited.
Therefore, how to provide a natural gas desulfurization decarbonization agent and a use method thereof, avoid the defects of high viscosity, difficult mass transfer and the like of the absorbent, and reduce the absorption cost is a difficult problem to be solved in the field.
Disclosure of Invention
In view of the above, the invention provides a natural gas desulfurization decarbonization agent and a use method thereof, and the natural gas desulfurization decarbonization agent disclosed by the invention solves the problems of high viscosity and difficult mass transfer of the traditional absorbent, and has the advantages of simple regeneration process and low energy consumption.
In order to achieve the above purpose, the invention adopts the following technical scheme:
the natural gas desulfurization decarbonization agent comprises the following components in parts by weight: 5-50 parts of aminosilane and 50-95 parts of organic solvent;
the structural formula of the aminosilane is
The R is 1 is-NH 2 、NH 2 C 2 H 4 NH-、NH 2 C 2 H 4 NHC 2 H 4 NH-、-NH(CH 2 ) 3 N(CH 3 ) 2 、-N(R 2 ) 3 Piperazinyl, methylpiperazinyl or cyclohexylamino; the R is 2 、R 3 And R is 4 Independently is-H, -CH 3 、-C 2 H 5 、-OCH 3 、-OCH 2 CH 3 or-CH (OCH) 3 ) 2 。
Preferably, the aminosilane is a liquid non-polymeric aminosilane.
Preferably, the organic solvent is one or more of fatty alcohol, diethylene glycol dimethyl ether and sulfolane.
Preferably, the fatty alcohol comprises one or more of monohydric alcohol, dihydric alcohol and trihydric alcohol;
wherein the molecular general formula of the monohydric alcohol is C n H 2n+1 OH，4≤n≤9；
The molecular general formula of the dihydric alcohol is C m H 2m (OH) 2 ，4≤m≤8；
The molecular general formula of the triol is C x H 2x-1 (OH) 3 X is more than or equal to 3 and less than or equal to 8; n, m and x are integers.
The invention also aims to provide a using method of the natural gas desulfurization and decarbonization agent, which specifically comprises the following steps:
will contain H 2 S and CO 2 Is introduced into natural gas desulfurization decarbonizing agent for absorption to obtainTo the purge gas.
Preferably, the time of the absorption is 30 to 45 minutes.
Preferably, the natural gas desulfurization and decarbonization agent is used and then is resolved to obtain the regenerated natural gas desulfurization and decarbonization agent, and the regenerated natural gas desulfurization and decarbonization agent can be used for recycling the hydrogen-containing gas 2 S and CO 2 Is absorbed by the gas.
Preferably, the temperature of the analysis is 40-70 ℃ and the time of the analysis is 1.5-3 h.
The chemical absorption reaction principle of the invention:
the natural gas containing acidic components passes through a desulfurization and decarbonization device, and the natural gas desulfurization and decarbonization agent is simultaneously contacted with the acidic components, and in the chemical absorption process, the natural gas desulfurization and decarbonization agent and H are carried out according to the chemical dissolution balance theory 2 S and CO 2 Chemical equilibrium is reached. The balance varies according to the solubility differences of the acidic components in the different types of natural gas desulfurization decarbonisers. The absorption time of the reaction is reasonably controlled, the chemical absorption efficiency of the reaction can be further improved, and the method has great significance for purifying natural gas and recycling acid component resources.
The chemical absorption reaction is exothermic reversible reaction with reduced volume, the absorption reaction is carried out under low temperature and high pressure, and the acidic components are removed from the natural gas in an absorption tower, so that the purpose of purifying the natural gas is realized; the desorption reaction is carried out at high temperature and low pressure, the acid component is resolved from the absorbent in the regeneration tower, and the absorbent is regenerated and recycled.
Principle of selective absorption of natural gas desulfurization decarbonization agent:
the solubility of the acidic component in the natural gas desulfurization decarbonization agent containing the aminosilane with different functional groups is different, the chemical balance achieved is different, and the H is controlled by the solubility difference 2 S (or CO) 2 ) The absorption rate of (2) may also be such that the absorbent has the property of selectively absorbing a component of the acid gas.
Depending on the number of nitrogen atoms, the aminosilanes contain "active" hydrogen-containing amines, primary and secondary amines being reactive with the natural gas acid component (H 2 S、CO 2 ) All react with active hydrogen, and the selectivity is not obvious. By secondary amine type aminosilane and H 2 S(2)、CO 2 (1) The reaction of (2) is as follows:
secondary amine type aminosilane absorbent and H 2 S reaction rate is controlled by a gas film; CO 2 Solubility is lower than H 2 S, the absorption rate is mainly controlled by a liquid film, and the chemical absorption rate is relatively slow; but from macroscopic chemical absorption, H 2 S、CO 2 Has no obvious difference with the reaction rate of the active hydrogen atoms.
Tertiary amine aminosilanes containing no "active" hydrogen, which are available in the molecule with H providing proton hydrogen 2 S, reacting (3); and CO with 2 The reaction then requires the participation of a solvent which provides proton hydrogen (4, 5).
And H is 2 S reaction:
with CO 2 The reaction:(4, slow reaction)
Thus, tertiary amino silanes preferentially and more rapidly absorb H selectively from acidic components 2 S, S. The invention provides tertiary amine aminosilane and primary amine aminosilane containing activated tertiary amine, which can be applied to selectively removing H in natural gas 2 S、CO 2 Is good forThe acid gas is independently recycled after desorption.
Compared with the prior art, the invention has the following beneficial effects:
compared with the traditional MEDA and MEA, the natural gas desulfurization decarbonization agent not only has the function of absorbing H by alkyl alcohol amine 2 S and CO 2 Has also lower saturated vapor pressure, specific heat capacity, high boiling point and good thermal stability, and is used for the preparation of a catalyst 2 S and CO 2 The gas-liquid mass transfer absorption process is less influenced by factors such as gas-liquid entrainment, volatilization, solute loss and the like, and is beneficial to H 2 S and CO 2 The loading capacity and the absorption rate are higher, and the problem that alcohol amine absorbent is easy to carry and volatilize in the absorption process and has high desorption temperature is avoided.
The invention adopts the low-viscosity high-boiling point nonvolatile organic solvent and liquid aminosilane to compound, can adjust the viscosity of the natural gas desulfurization decarbonization agent and promote H 2 S and CO 2 The mass transfer absorption of (2) can enhance the mass transfer efficiency, reduce the solvent loss and reduce H 2 S and CO 2 Energy consumption of the desorption process. The organic solvent which is not easy to volatilize is used for replacing water, so that the energy can be greatly saved and the solvent loss can be reduced.
The invention can also realize H 2 S and CO 2 Is favorable for the independent recycling of the acid gas after desorption.
Detailed Description
The invention provides a natural gas desulfurization decarbonization agent, which comprises the following components in parts by weight: 5-50 parts of aminosilane and 50-95 parts of organic solvent;
the structural formula of the aminosilane is
The R is 1 is-NH 2 、NH 2 C 2 H 4 NH-、NH 2 C 2 H 4 NHC 2 H 4 NH-、-NH(CH 2 ) 3 N(CH 3 ) 2 、-N(R 2 ) 3 Piperazinyl groupMethyl piperazinyl or cyclohexylamino; the R is 2 、R 3 And R is 4 Independently is-H, -CH 3 、-C 2 H 5 、-OCH 3 、-OCH 2 CH 3 or-CH (OCH) 3 ) 2 。
In the invention, the mass parts of the raw materials are preferably 20-40 parts of aminosilane and 60-80 parts of organic solvent; more preferably 30 parts of aminosilane and 70 parts of organic solvent.
In the present invention, the aminosilane is a liquid non-polymeric aminosilane.
In the present invention, the aminosilane is preferably
In the present invention, the organic solvent is preferably one or more of aliphatic alcohol, diethylene glycol dimethyl ether and sulfolane.
In the invention, the fatty alcohol comprises one or more of monohydric alcohol, dihydric alcohol and trihydric alcohol;
wherein the molecular general formula of the monohydric alcohol is C n H 2n+1 OH，4≤n≤9；
The molecular general formula of the dihydric alcohol is C m H 2m (OH) 2 ，4≤m≤8；
The molecular general formula of the triol is C x H 2x-1 (OH) 3 X is more than or equal to 3 and less than or equal to 8; n, m and x are integers.
In the present invention, the organic solvent is preferably monohydric octanol C 8 H 17 OH, dibasic butanol C 4 H 8 (OH) 2 Monobasic butanol C 4 H 9 OH, ternary butanol C 4 H 7 (OH) 3 Or monohydric amyl alcohol C 5 H 11 OH。
The invention also provides a using method of the natural gas desulfurization decarbonization agent, which comprises the following steps:
will contain H 2 S and CO 2 Introducing the gas into a natural gas desulfurization decarbonization agent for absorption to obtain purified gas.
In the present invention, the time of the absorption is 30 to 45 minutes, preferably 35 minutes.
In the present invention, the absorption temperature is preferably room temperature.
In the invention, the natural gas desulfurization and decarbonization agent is used and then is resolved to obtain the regenerated natural gas desulfurization and decarbonization agent, and the regenerated natural gas desulfurization and decarbonization agent can be used for recycling H-containing materials 2 S and CO 2 Is absorbed by the gas.
In the present invention, the temperature for the analysis is 40 to 70 ℃, preferably 50 to 60 ℃, and more preferably 55 ℃.
In the present invention, the time for the analysis is 1.5 to 3 hours, preferably 2 hours.
The following description of the technical solutions in the embodiments of the present invention will be clear and complete, and it is obvious that the described embodiments are only some embodiments of the present invention, but not all embodiments. All other embodiments, which can be made by those skilled in the art based on the embodiments of the invention without making any inventive effort, are intended to be within the scope of the invention.
Example 1
Preparing a natural gas desulfurization decarbonization agent: and uniformly mixing 30 parts of N- (beta-aminoethyl) -gamma-aminopropyl triethoxysilane and 70 parts of sec-octanol to obtain the natural gas desulfurization decarbonization agent.
And measuring the desulfurization and decarbonization rate. H 2 S, determination: GB/T14678-93 determination of air mass-hydrogen sulfide, methyl mercaptan, dimethyl sulfide and dimethyl disulfide; CO 2 And (3) measuring: the method for testing carbon dioxide in the air of the GB/T18204.24-2000 public place comprises the following steps of:
(1) 0.5g of natural gas (H is contained in natural gas) 2 S1500 ppmw (parts per million by mass) and CO 2 1200ppmw, the same applies below) 10g of zinc acetate with a concentration of 0.05486mol/LAdding excessive iodine solution into acetic acid solution, standing in dark for 30min, titrating with 0.01mo1/L sodium thiosulfate solution, and testing H in natural gas 2 S content, designated M 0 ；
(2) Introducing 0.5g of natural gas into a 1L pressure vessel containing 150g of desulfurization and decarbonization agent, and standing for 30min; then use N 2 Blowing the gas treated by the desulfurization and decarbonization agent into a 1L pressure vessel (10 g of zinc acetate acetic acid solution with the concentration of 0.05486mol/L in the vessel), standing for 30min, adding excessive iodine solution, standing for 30min in a dark place, titrating with 0.01mo1/L sodium thiosulfate solution, and testing H in the natural gas after desulfurization 2 S content, denoted M;
(3)CO 2 concentrated absorption solution: 2.8g of barium hydroxide and 0.16g of barium chloride were weighed and dissolved in 800ml of water, 3ml of n-butanol was added, shaken well and diluted with water to 1000ml.
Oxalic acid standard solution: 0.5637g oxalic acid solid is weighed, dissolved in water and diluted to 1000ml;
(4) 0.5g of natural gas is fed into 50ml of CO 2 In the concentrated absorption liquid, after the precipitation in the absorption liquid is complete, the residual barium hydroxide content is titrated by oxalic acid standard solution, and the CO in the natural gas is tested 2 Content, denoted as m o ；
(5) Introducing 0.5g of natural gas into 150g of desulfurization and decarbonization agent, then introducing into 50ml of carbon dioxide concentrated absorption liquid, titrating the residual barium hydroxide content by using oxalic acid standard solution after the precipitation in the absorption liquid is complete, testing the carbon dioxide content in the decarbonized natural gas, and marking as m;
(6) Calculating desulfurization and decarbonization rate E (%):
the detection results are shown in Table 1.
Comparative example 1
The desulfurization and decarbonization rate of 30% aqueous solution of Methyldiethanolamine (MDEA) was measured by the same method as in example 1, and the measurement results are shown in Table 1.
Comparative example 2
The desulfurization and decarbonization rate of 30% by mass of an aqueous Ethanolamine (EA) solution was measured in the same manner as in example 1, and the measurement results are shown in Table 1.
TABLE 1 desulfurization and decarbonization rates of absorbent
As can be seen from Table 1, the aminosilane desulfurization and decarbonization agent disclosed by the invention has a higher desulfurization and decarbonization rate than the alcohol amine desulfurization and decarbonization agent.
Example 2
Uniformly mixing 30 parts of N-aminoethyl-3-aminopropyl methyl dimethoxy silane (the structural formula is shown below) and 70 parts of diethylene glycol dimethyl ether to obtain the desulfurization decarbonization agent. The desulfurization and decarbonization rate was measured in the same manner as in example 1, and the results are shown in Table 2.
Example 3
Uniformly mixing 30 parts of N-aminoethyl-3-aminopropyl methyl dimethoxy silane and 70 parts of sec-octyl alcohol to obtain the desulfurization decarburization agent. The desulfurization and decarbonization rate was measured in the same manner as in example 1, and the results are shown in Table 2.
Example 4
30 parts of 3-dimethylaminopropyl (dimethoxy) methylsilane (structural formula is shown below) and 70 parts of sec-octanol are uniformly mixed to obtain the desulfurization decarbonization agent. The desulfurization and decarbonization rate was measured in the same manner as in example 1, and the results are shown in Table 2.
TABLE 2 desulfurization and decarbonization rates of absorbent
Analysis of the data in Table 2 shows that the aminosilanes used in examples 2 and 3 are the same and different in solvents, and that the desulfurization and decarbonization rates are better with sec-octanol as the solvent, but the overall trends are not significantly different; the aminosilane used in example 4 was tertiary amine type without active hydrogen, and the desulfurization and decarbonization rate was lowered due to the slower absorption reaction rate as compared with the aminosilane containing active hydrogen in example 3.
Example 5
40 parts of 3- (diethoxymethylsilyl) propylamine (the structural formula is shown below) and 60 parts of diethylene glycol dimethyl ether are uniformly mixed to obtain the desulfurization decarburizing agent. The desulfurization and decarbonization rate was measured in the same manner as in example 1, and the results are shown in Table 3.
Example 6
50 parts of 3- (diethoxymethylsilyl) propylamine, 40 parts of diethylene glycol dimethyl ether and 10 parts of isopropanol are uniformly mixed to obtain the desulfurization decarburizing agent. The desulfurization and decarbonization rate was measured in the same manner as in example 1, and the results are shown in Table 3.
Example 7
60 parts of 3- (diethoxymethylsilyl) propylamine, 20 parts of sulfolane, 10 parts of isopropanol and 10 parts of diethylene glycol dimethyl ether are uniformly mixed to obtain the desulfurization decarbonization agent. The desulfurization and decarbonization rate was measured in the same manner as in example 1, and the results are shown in Table 3.
TABLE 3 desulfurization and decarbonization rates of absorbent
The natural gas desulfurization and decarbonization agent prepared by the invention has obvious desulfurization and decarbonization rate through the table 3.
In the present specification, each embodiment is described in a progressive manner, and each embodiment is mainly described in a different point from other embodiments, and identical and similar parts between the embodiments are all enough to refer to each other.
The previous description of the disclosed embodiments is provided to enable any person skilled in the art to make or use the present invention. Various modifications to these embodiments will be readily apparent to those skilled in the art, and the generic principles defined herein may be applied to other embodiments without departing from the spirit or scope of the invention. Thus, the present invention is not intended to be limited to the embodiments shown herein but is to be accorded the widest scope consistent with the principles and novel features disclosed herein.
Claims (5)
1. The natural gas desulfurization decarbonization agent is characterized by comprising the following components in parts by weight: 40 parts of 3- (diethoxymethyl-silica-based) propylamine, 60 parts of diethylene glycol dimethyl ether or 50 parts of 3- (diethoxymethyl-silica-based) propylamine, 40 parts of diethylene glycol dimethyl ether, 10 parts of isopropanol or 60 parts of 3- (diethoxymethyl-silica-based) propylamine, 20 parts of sulfolane, 10 parts of isopropanol and 10 parts of diethylene glycol dimethyl ether.
2. The method for using the natural gas desulfurization decarbonization agent as claimed in claim 1, which is characterized by comprising the following steps:
will contain H 2 S and CO 2 Introducing the gas into a natural gas desulfurization decarbonization agent for absorption to obtain purified gas.
3. The method for using a natural gas desulfurization and decarbonization agent according to claim 2, wherein the absorption time is 30-45 min.
4. A method of using a natural gas desulfurization and decarbonization agent as claimed in claim 2 or 3, wherein the regenerated natural gas desulfurization and decarbonization agent is obtained by analysis after the use of the natural gas desulfurization and decarbonization agent, and the regenerated natural gas desulfurization and decarbonization agent can be recycled to the process containing H 2 S and CO 2 Is absorbed by the gas.
5. The method for using a natural gas desulfurization and decarbonization agent according to claim 4, wherein the analysis temperature is 40-70 ℃ and the analysis time is 1.5-3 h.
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