Patent Description:
<CIT> relates to a process for removing acidic gas constituents such as CO<NUM> and H<NUM>S from gases using an absorption medium, to the absorption medium itself and to its use.

The present invention is set out in the claims.

In particular, the present invention provides a solvent for recovery of carbon dioxide from gaseous mixture, comprising:.

a sulfolane having a weight percentage between <NUM> wt% and <NUM> wt%,
wherein the solvent contains less than <NUM>% by weight of water and has a single liquid aqueous phase.

The present invention also provides a method for removing CO<NUM> from a stream, comprising the steps of:.

Any disclosure which does not fall within the scope of the claims is included for illustrative purposes.

This disclosure is directed towards a solvent (not necessarily in full accordance with the claims) for recovery of carbon dioxide from gaseous mixture having an alkanolamine, reactive amines acting as promoter or activators, and a carbonate buffer. One specific solvent contains less than about <NUM>% by weight of dissolving medium water and glycol (e.g., polyethylene glycol) and has a single liquid phase. Another specific solvent contains less than about <NUM>% by weight of dissolving medium water and glycol (e.g., polyethylene glycol) and has a single liquid phase. Another specific solvent contains less than about <NUM> %> by weight of dissolving medium water and sulfolane and has a single liquid phase.

Additional features of the disclosure will become apparent to those skilled in the art upon consideration of the following detailed description of illustrative embodiments exemplifying the best mode of carrying out the disclosure as presently perceived.

As used herein, the term "solvent" can refer to a single solvent or a mixture of solvents.

This disclosure includes several aspects and provides methods and solvents that, when used alone or in combination, may significantly reduce or eliminate carbon dioxide (CO<NUM>) emissions from industrial plants that burn solid fuels, particularly coal-fired power plants. This disclosure is directed to CO<NUM> capture/sequestration from flue gases CO<NUM> emissions should also be applicable to CO<NUM> capture from gas and oil fired boilers, combined cycle power plants, coal gasification, and hydrogen plants, biogas plants.

As shown in <FIG>, the vapor and liquid phases are contact in a small cross-section. In treating the emissions, the absorption step involves removal of acid gases and other components from the gas phase by transport into the liquid phase. The gas-liquid interface separates the phases. An absorbing gas dissolves into the liquid at the interface, then diffuses across a thin layer of liquid (termed the diffusion layer) of one specific solvent. As it diffuses, the gas meets the reactive absorbent component in one specific solvent, reacts with it, and generates heat and reaction products such as carbonate. Reaction products can diffuse into the bulk liquid while the liberated heat of reaction heats the liquid. In one example, there is a mixture of tertiary amine/hindered amine, reactive amines (e.g., a polyamine activator), carbonate buffer, a dissolving medium of water and physical polyethylene glycol as to solvent system remain as a single liquid phase in removing acidic gases from gaseous mixture.

In embodiment, one specific solvent for absorbing CO<NUM> includes alkanolamines, which can be any one of compounds represented by following formulae (I) to (III) or a mixture thereof:
<CHM>
<CHM>
<CHM>
in the formulae (I) to (III): x and y respectively satisfy relationship: <NUM> less than or equal to <NUM> and <NUM>. less than or equal to <NUM>; and R<NUM>, R<NUM>, R<NUM>, and R<NUM> represent -- CiHjOkNl (where i=<NUM> to <NUM>, j=<NUM> to <NUM>, k=<NUM> to <NUM>, and l=<NUM> to <NUM>).

In one illustrative solvent, reactive amines can be any one of nitrogen containing compounds represented by following formulae (IV) to (XIII) or mixture thereof. Reactive amines may be nitrogen-containing compound having a secondary nitrogen in a ring or a nitrogen-containing compound having a tertiary nitrogen in a ring.

In another illustrative solvent, reactive amines can be a nitrogen-containing compound having secondary and tertiary nitrogen in a ring.

In another illustrative solvent, reactive amines can be a nitrogen-containing compound having a nitrogen in a substituent group branching from the ring.

In another illustrative solvent, reactive amines can be nitrogen-containing compound may be a nitrogen-containing compound having a primary nitrogen in a substituent group branching from the ring.

In another illustrative solvent, reactive amines can be a nitrogen-containing compound having three nitrogen atoms or more in a molecule thereof.

In another illustrative solvent, reactive amines can be a nitrogen-containing compound having in a molecule thereof all of primary, secondary, and tertiary nitrogens. <CHM>
<CHM>.

In one specific solvent, the second compound component may be any one of nitrogen-containing compounds represented by following formulae (XIV) to (XIX) or a mixture thereof:
<CHM>.

In one specific solvent, the reactive amine may be a nitrogen-containing compound represented by following formula (XX):
<CHM>
in the formula (XX): R<NUM>, R<NUM>, R<NUM> and R<NUM> represent --CiHjOkNl (where i=<NUM> to <NUM>, j=<NUM> to <NUM>, k=<NUM> to <NUM>, and l=<NUM> to <NUM>), and R<NUM> represents --CiHjOkNl (where i=<NUM> to <NUM>, j=<NUM> to <NUM>, k=<NUM> to <NUM>, and l=<NUM> to <NUM>).

In one specific solvent, the reactive amine may be piperazine, N-<NUM>-Hydroethyl Piperazine, <NUM>-aminomethyl piperazine or mixture thereof. <CHM>
<CHM>
<CHM>.

In one illustrative solvent, one of one specific solvent components can be represented by polyethylene glycol (PEG) represented by the following formulae (XXI) and / or physical pressure driven solvent or mixture thereof:.

Polyethylene Glycol (C2nH4n+<NUM>On+<NUM>).

In one specific solvent, alkanolamines may be contained in an amount in a range from equal to or larger than <NUM> wt % to equal to or less than <NUM> wt %, reactive amines may in an amount in a range from equal to or larger than <NUM> wt % to equal to or less than <NUM> wt %, and a total amount of the alkanolamine and reactive amines may be more than <NUM> wt % to equal to or less than <NUM> wt %.

In one specific solvent, the alkanolamine may be represented by the formula (I), where each of R<NUM> and R<NUM> is H.

In one specific solvent, the alkanolamine may be represented by the formula (I), where x is <NUM> to <NUM> and y is <NUM> to <NUM>.

In one specific solvent, alkanolamines may be represented by the formula (I), where R<NUM> is H and R<NUM> is -CmHnOoNp (where m=<NUM> to <NUM>, n=<NUM> to <NUM>, o=<NUM> to <NUM>, and p=<NUM> to <NUM>).

In one specific solvent, the alkanolamine may be represented by the formula (I), where x is <NUM> to <NUM>, y is <NUM> to <NUM>, and R<NUM> is CH<NUM>, C<NUM>H<NUM>, C<NUM>H<NUM>, or C<NUM>H<NUM>.

In one specific solvent, the alkanolamine may be represented by the formula (I), where R1 and R<NUM> represent -CmHnOoNp (where m=<NUM> to <NUM>, n=<NUM> to <NUM>, o=<NUM> to <NUM>, and p=<NUM> to <NUM>).

In one specific solvent, the alkanoamine may be represented by the formula (I), where x is <NUM>, y is <NUM>, R<NUM> is CH<NUM>, and R<NUM> is C<NUM>H<NUM>OH.

An absorbent liquid for absorbing CO<NUM> or H<NUM>S or both from gas according to certain embodiments includes a cyclic amine compound having one nitrogen in a ring. In one specific solvent, the cyclic amine having one nitrogen in a ring may be a cyclic amine having one nitrogen in a <NUM>-membered ring, <NUM>-membered ring, or <NUM>-membered ring.

In one specific solvent, the cyclic amine having one nitrogen in a <NUM>-membered ring, <NUM>-membered ring, or <NUM>-membered ring may be pyrrolidine (PR), piperidine (PZ), or hexamethyleneimine (HMI).

In one specific solvent, the cyclic amine compound having one nitrogen in a ring may be a nitrogen containing compound having a primary nitrogen in a substituent group branching from the ring.

In one specific solvent, the nitrogen-containing compound having a primary nitrogen in a substituent group branching from the ring may be aminomethylpiperidine or aminoethylpiperidine.

In one specific solvent, the cyclic amine compound having one nitrogen in a ring may be a nitrogen-containing compound having a hydroxyl group in a <NUM>-membered ring, <NUM>-membered ring, or <NUM>-membered ring.

In one specific solvent, the nitrogen-containing compound having a hydroxyl group in a <NUM>-membered ring, <NUM>-membered ring, or <NUM>-membered ring may be piperidinol (PDN).

An absorbent liquid includes a mixture of one specific solvent, and an alkanolamine. In one specific solvent, the alkanolamine may be monoethanolamine (MEA), ethylaminoethanol (EAE), triethanolamine, N-methyldiethanolamine (MDEA), diisopropanolamine, diglycolamine, or a mixture thereof.

A process for removing CO<NUM> or H<NUM>S or both a includes an absorption tower that allows gas containing CO<NUM> or H<NUM>S or both and an absorbent liquid to be in contact with each other to remove CO<NUM> or H<NUM>S or both from the gas; and a regeneration tower that regenerates a solution which has absorbed the CO<NUM> or H<NUM>S or both, the absorption tower reusing the solution regenerated at the regeneration tower by removing the CO<NUM> or H<NUM>S or both from the solution.

In one embodiment, one specific solvent for recovery of carbon dioxide from gaseous mixture includes hindered amine, reactive amine, Polyethylene glycol, and a alkali carbonate buffer. The remaining solvent may be water.

Reactive amines may be a piperazine and its derivative such as piperazine, <NUM>-aminomethyl piperazine, N-aminoethylpiperazine (in accordance with the claims), hydroxyethylpiperazine, <NUM>-(<NUM>-pyrrolidyl)piperidine, <NUM>-(<NUM>-pyrrolidyl)piperazine, <NUM>-(<NUM>-piperidyl)-piperidine, <NUM>-(<NUM>-piperazinyl)piperidine, or <NUM>-(<NUM>-piperazinyl)piperazine, <NUM>-aminomethyl piperazine. The reactive amine may be ethylenediamine, dimethyl ethylenediamine, pyrazolidine, imidazolidine, <NUM>-(<NUM>-pyrrolidyl)-pyrrolidine, <NUM>-(<NUM>-imidazolidyl) imidazolidine or mixture thereof. One example includes a solvent having hindered amine, mixture of active amine piperazine and N-<NUM> Hydroethyl Piperazine, a carbonate buffer, polyethylene glycol, and water.

One embodiment may include a solvent with polyethylene glycol, any of a class of organic compounds belonging to the alcohol family; in the molecule of a glycol, two hydroxyl (OH) groups are attached to different carbon atoms. The term is often applied to the simplest member of the class, ethylene glycol. Ethylene glycol, also called <NUM>,<NUM>-ethanediol, molecular formula HOCH<NUM>CH<NUM>OH, is a colourless, oily liquid possessing a sweet taste and mild odor. It can be produced commercially from ethylene oxide, which is obtained from ethylene. Further, propylene glycol, also called <NUM>,<NUM>-propanediol, resembles ethylene glycol in its physical properties. Other glycols include <NUM>,<NUM>-butanediol, <NUM>,<NUM>-butanediol, <NUM>-ethyl-<NUM>,<NUM>-hexanediol, and <NUM>-methyl-<NUM>-propyl-<NUM>,<NUM>-propanediol, methoxytriglycol and others and are suitable herewith.

One specific solvent may contain hindered or tertiary amines that act as high CO<NUM> loading carrier as the base solvent to increase the capacity of the CO<NUM> capture solvent. Hindered amine / tertiary amine may be N-methyldiethanolamine (MDEA), <NUM>-(<NUM>-aminoethoxy)ethanol, Aminoethylethanolamine (AEEA), <NUM>-amino-2methyl-<NUM>-proponal (AMP), <NUM>-(ethyamino)-ethanol (EAE), <NUM>-(methylamino)-ethanol (MAE), <NUM>-(diethylamino)-ethanol (DEAE), diisopropanolamine (DIPA), methylaminopropylamine (MAPA), <NUM>-aminopropanol (AP), <NUM>,<NUM>-dimethyl-<NUM>,<NUM>-propanediamine (DMPDA), <NUM>-amino-<NUM>-cyclohexylaminopropane (ACHP), diglycolamine (DGA), <NUM>-amino-<NUM>-propanol (MIPA), <NUM>-methyl-methanolamine (MMEA); Di ethyl ethanol amine (DEEA). MDEA and AMP are the only alkanol amines in accordance with the claims.

The solvent of the invention contains a carbonate buffer. The pH may range for a carbonate buffer may be between <NUM> and <NUM>. Carbonate in one specific solvent increases the pH of one specific solvent. This high pH allows for increased carbon dioxide capture in the form of bicarbonate salts. The carbonate can be regenerated when one specific solvent is heated. In some instances percarbonate may contribute to the buffer system.

Suitable carbonate buffer salts are described herein. The amount of carbonate buffer salt used in the buffer system is an amount that is sufficient, when used with the remaining components, to raise salivary pH to a pH of about <NUM> or more, about <NUM> or more, and about <NUM> or more (e.g., about <NUM>-<NUM>), irrespective of the starting pH.

In another embodiment, the carbonate salt is selected from the group consisting of sodium carbonate, potassium carbonate, calcium carbonate, ammonium carbonate, and magnesium carbonate. In yet another embodiment, the bicarbonate salt is selected from the group consisting of sodium bicarbonate, potassium bicarbonate, calcium bicarbonate, ammonium bicarbonate, and magnesium bicarbonate. In one embodiment, the binary buffer system comprises sodium carbonate and sodium bicarbonate. In another embodiment, the sodium bicarbonate is desiccant-coated sodium bicarbonate.

The amount of carbonate buffer and reactive amine piperazine in the solution is limited by the solubility of both components in water, thus resulting in solid solubility limit for aqueous solutions. At <NUM>, the solubility of potassium carbonate buffer in a CO<NUM> rich solution is <NUM> and the solubility of piperazine in water is approximately <NUM>. With the solid solubility limitation, the resulting lower concentration can result in slow reaction rate and low solution capacity. By combining piperazine and carbonate buffer solubility in polyethylene glycol and aqueous solutions, the resultant solubility increases.

Reactive amines such as piperazine and CO<NUM> react, it undergoes equilibrium reaction to form piperazine carbamate and piperazine dicarbamate and some free and bound piperazine. Because of the addition of carbonate buffer salt; which react with free and bound piperazine in reacting more CO<NUM> to form piperazine carbamate and piperazine dicarbamate.

The ratio of equivalents of carbonate salt to equivalents of reactive amine can be between <NUM> - <NUM>. The concentrations of the reactive amine and carbonate salt can be between <NUM> - <NUM> equivalents/Kg H<NUM>O or <NUM> and <NUM> equivalents/Kg H<NUM>O. The amount of piperazine and carbonate buffer salt can be adjusted based on the solubility in water and polyethylene glycol.

In one example, one specific solvent and method of use for the removal of CO<NUM> from flue gas, natural gas, hydrogen gas, synthesis gas, and other process and waste gas streams. One specific solvent may contain a carbonate buffer, a reactive amine, a hindered amine, and a polyethylene glycol, resulting in the solution pH between (<NUM> - <NUM>) in absence of CO<NUM>. The reactive amine <NUM> wt% to <NUM> wt% with the total concentration limited by the solid solubility of the reactive amine in aqueous and polyethylene glycol solution or of the carbonate buffer salt from <NUM> wt% - <NUM> wt% with total concentration limited by the solid solubility in aqueous solution. This chemical solvent is designed to increase the rate of CO<NUM> removal to improve the efficiency of a removal process.

Piperazine is freely soluble in water and solubility in ethylene glycol up to about <NUM> wt%. Carbonate buffer salt solubility in water is <NUM>/<NUM> at <NUM>.

The temperature of the solution when contacting with the gaseous stream may be between approximately <NUM> - <NUM>. The rate constant for the reaction of CO<NUM> with the piperazine derivative (KPZ) may be at least <NUM><NUM>/mol-s at <NUM>, or at least <NUM><NUM>/mol-s at <NUM>.

In one embodiment, one specific solvent has a reactive amine in concentration between about <NUM> wt% and <NUM> wt%.

In yet another embodiment, one specific solvent has a alkanolamine in a concentration between about 10wt% and <NUM> wt%.

In accordance with the claims, the solvent has a carbonate buffer with a concentration between about <NUM>. 15wt% - <NUM> wt%.

In yet another embodiment, one specific solvent has a solute concentration between about <NUM> wt% - <NUM> wt%.

In yet another embodiment, one specific solvent has a tertiary balance to keep one specific solvent or solvent system as a single liquid phase.

In yet another embodiment, the solvent the alkanolamine has a weight percentage between <NUM> wt% and <NUM> wt% and is selected from group comprising N-methyldiethanolamine (MDEA), <NUM>-amino-2methyl-<NUM>-proponal (AMP); the reactive amines have a weight percentage between <NUM> wt% and <NUM> wt% and is selected from group comprising piperazine, N aminoethylpiperazine (AEP); and the glycol has a weight percentage between <NUM> wt% and <NUM> wt%.

In yet another embodiment, the solvent the alkanolamine has a weight percentage between <NUM> wt% and <NUM> wt%; the reactive amines have a weight percentage between <NUM> wt% and <NUM> wt%; and the glycol has a weight percentage between <NUM> wt% and <NUM> wt%.

In yet another embodiment, the solvent the alkanolamine has a weight percentage between <NUM> wt% and <NUM> wt%; the reactive amines have a weight percentage between <NUM> wt% and <NUM> wt%; and the sulfolane has a weight percentage between <NUM> wt% and <NUM> wt%.

In another embodiment, a method of removing CO<NUM> from a gaseous stream including: contacting a gaseous stream with a solution wherein the solution is formed by combining: alkanolamines, a reactive amine , an carbonate salt, poly ethylene glycol and water; whereby the contact removes CO<NUM> from the gaseous stream; and regenerating the solution. The concentrations may be limited by the solubility of the components at a temperature and contact of the exhaust gaseous stream with one specific solvent removes CO<NUM> from the gaseous stream; and regenerating the solution.

The regenerating may include heating CO<NUM>-rich solution, which may occur at a temperature of approximately <NUM> - <NUM>, approximately <NUM>. An additive such as an antifoaming agent, an antioxidant, a corrosion inhibitor (e.g. vanadium oxide or a chromate), a flocculation aid, or a mixture of two or more additives may be included as part of the solution.

In another embodiment, the method of removing CO<NUM> from a gaseous stream may further include applying a water wash system, wherein the water wash system collects the volatile alkanolamine and reactive amine from treated gaseous stream. The regeneration of the solution may occur in a vacuum stripper column, and the solution may be returned to contact with the gaseous stream after regeneration.

Other components of a gaseous stream, such as COS may also be removed by the method of this disclosure. The gaseous stream may be from a coal-fired power plant, or it may be flue gas, natural gas, hydrogen gas, synthesis gas or a waste gas stream.

<FIG> is a schematic diagram of an apparatus for removing acidic gases especially CO<NUM>. As shown in <FIG>, gas is allowed to enter to an absorption tower <NUM> through a CO<NUM> - containing gas-feed. In a packed portion, the gas placed in the absorption tower <NUM> is brought into contact in a counter flow with a CO<NUM> absorbent liquid fed from <NUM>, and CO<NUM> is absorb and removed from the gas by the absorbing liquid, and the resultant gas is discharge from the top as treated gas. The absorbent liquid fed to the absorption tower <NUM> absorb CO<NUM>, and is led to heat exchanger and heated and led to a regeneration tower <NUM>. In the regeneration tower <NUM>, the absorbent liquid flows through a packed portion towards the lower portion of the tower. During this time, CO<NUM> is removed to regenerate the absorbent liquid. The regenerated absorbent liquid is led by a pump to the heat exchanger and fed back to the absorption tower <NUM> through an absorbent liquid feed inlet line <NUM>.

On the other hand, in the upper portion of the regeneration tower <NUM>, the CO<NUM> removed from the absorbent liquid is brought into contact with a reflux water, and cooled by a regeneration tower reflux condenser and, in a reflux drum, the CO<NUM> separated from the reflux water formed by condensing water vapor accompanying the CO<NUM>, and led to a CO<NUM> recovery step. The reflux water is fed by a reflux water pump to the regenerator tower <NUM>. This embodiment briefly describes an overview of the CO<NUM> capture process description.

Heat to produce steam to maintain driving force for CO<NUM>, For the CO<NUM>, to be transferred from the liquid to the gas phase there needs to be driving force on the basis of partial pressure. Thus, steam acts in such a way as to provide this driving force so that the mass transfer of CO<NUM> from the liquid to the gas phase is enhanced. This also has energy associated with it, which contributes to the overall reboiler duty. This can be obtained by finding out the amount of water associated with the pure CO<NUM> steam produced as this energy in the form of water is lost and needs to be provided by the reboiler. The stripping heat consists of the following: <MAT>.

One specific solvent loaded with CO<NUM> in the absorber may be heated up to stripper temperature for the regeneration of CO<NUM>. One specific solvent stream can be pre-heated in the lean-rich cross heat exchanger and then additional heat may be used to maintain the temperature of one specific solvent in the stripper.

The contributing factors to the sensible heat are solvent flow, specific heat capacity of one specific solvent and the temperature increase. Thus, the only parameter that can be varied is one specific solvent flow which further depends on the concentration of one specific solvent and one specific solvent loadings. This can be decreased by circulating less solvent and maintaining the same CO<NUM> production rate. This is checked by means of comparing the Net Capacity of a solvent which is defined as the difference in the loading at the absorption and desorption conditions.

The CO<NUM> which is reversibly bound to one specific solvent needs to be regenerated. The heat of desorption is equivalent to the heat of absorption.

For the CO<NUM> to be transferred from the liquid to the gas phase there needs to be driving force in the basis of the partial pressure. Thus steam acts in such a way as to provide the driving force so that the mass transfer of CO<NUM> from the liquid to the gas phase is enhanced. This also has energy associated with it, which contributes to the overall reboiler duty. This can be obtained by finding out the amount of water associated with the pure CO<NUM> steam produced as this energy in the form of water is lost and needs to be provided by the rebuilder. The stripping heat consists of the following: <MAT> Where <MAT> stands for heat of vaporization if water and <MAT> is the partial pressure of CO<NUM> that would be equilibrium with the rich solution at the bottom of the absorber. Thus, finding EXAMPLES
The disclosure will be further described in connection with the following examples, which are set forth for purposes of illustration only.

As the rate activator for the CO<NUM> absorption is piperazine and its derivative, the limitation with piperazine is its high volatility. It has highest reaction kinetics among its derivatives. It is white crystals which need more water to foam a clear solutions or need Polyethylene glycol to solubilize it. But because of the high volatility the loss of the piperazine is high and to minimize the volatility loss in the solvent, piperazine component is partly or completely replaced by rate activator such as N-<NUM>-hydroethyl piperazine whose vapor pressure is <NUM>% less than piperazine.

Below is the composition and characteristics of another exemplary solvent (not in accordance with the claims).

The densities of were measured using a <NUM> ×<NUM>-<NUM>m<NUM> (at <NUM>) Gay-Lussac pycnometer. For each run, the pycnometer containing the solvent solution was put in a constant temperature bath. The bath temperature was controlled within ± <NUM> of the desired temperature level using a circulator temperature controller. Once the solution reached the desired temperature, it was weighed to within ±<NUM> with an analytical balance. Each reported density data is the average of at least three measurements.

The viscosities of solutions were measured using Cannon Fenske Viscometer. For each viscosity measurement, the temperature was controlled within ±<NUM> of the desired level with a circulator temperature controller. The viscometers containing samples were immersed in a thermostatic bath and allowed to equilibrate to the set point temperature for at least <NUM>. Later, the efflux time of samples was measured manually with a digital stopwatch having an accuracy of <NUM>. The efflux time is measured by allowing meniscus to pass between two specific marks. The kinematic viscosity was obtained by multiplying efflux time in seconds with the respective viscometer constant. The dynamic viscosity of the samples is calculated by multiplying the kinematic viscosity values with their corresponding density values. Each viscosity data is the average of at least three measurements.

<FIG> describes viscosity in mPa. sec and density in kg/m<NUM> (on Y-axis) w. t temperature °C (on X-axis) for the solvent Si. It is observed that viscosity and density decreases with the increase in temperature.

These measurements can determine the relationship between partial pressure of CO<NUM> and the subsequent loading of the solvent at different temperatures. This data can be used be used to do a first assessment of the solvent performance.

Specific rate of absorption increases with CO<NUM> partial pressure.

Claim 1:
A solvent for recovery of carbon dioxide from gaseous mixture, comprising:
(a) an alkanolamine selected from the group comprising N-methyldiethanolamine (MDEA) and <NUM>-amino-<NUM>-methyl-<NUM>-propanol (AMP) and having a weight percentage between <NUM> wt% and <NUM> wt%,
(b) piperazine amines, wherein the piperazine amine is N-aminoethylpiperazine (AEP) having a weight percentage between <NUM> wt% and <NUM> wt%,
(c) a carbonate buffer having a weight percentage between <NUM> wt% and <NUM> wt%,
(d) water, and
(e) a glycol having a weight percentage between <NUM> wt% and <NUM> wt%, or
a sulfolane having a weight percentage between <NUM> wt% and <NUM> wt%,
wherein the solvent contains less than <NUM>% by weight of water and has a single liquid aqueous phase.