WO2021092215A1

WO2021092215A1 - Treatment of acid gases using molten alkali metal borates and associated methods of separation, and processes for regenerating sorbents and associated systems

Info

Publication number: WO2021092215A1
Application number: PCT/US2020/059167
Authority: WO
Inventors: Trevor Alan Hatton; Takuya Harada; Cameron G. HALLIDAY
Original assignee: Massachusetts Institute Of Technology
Priority date: 2019-11-07
Filing date: 2020-11-05
Publication date: 2021-05-14
Also published as: EP4054743A1; CA3160467A1; JP2023501372A

Abstract

The removal of acid gases (e.g., non-carbon dioxide acid gases) using non-COi acid gas sorbents that include salts in molten form, and related systems and methods, are generally described. Processes for regenerating sorbents at high temperatures, and associated systems, are also generally described.

Description

TREATMENT OF ACID GASES USING MOLTEN ALKALI METAL BORATES AND ASSOCIATED METHODS OF SEPARATION, AND PROCESSES FOR REGENERATING SORBENTS AND ASSOCIATED SYSTEMS RELATED APPLICATIONS This application claims priority under 35 U.S.C. § 119(e) to U.S. Provisional Patent Application No.62/971,488, filed February 7, 2020, and entitled “Treatment of Acid Gases Using Molten Alkali Metal Borates, and Associated Methods of Separation”; to U.S. Provisional Patent Application No.62/988,436, filed March 12, 2020, and entitled “Processes for Regenerating Sorbents, and Associated Systems”; to U.S. Provisional Patent Application No.62/979,628, filed February 21, 2020, and entitled “Processes for Regenerating Sorbents, and Associated Systems”; and to U.S. Provisional Patent Application No.62/932,410, filed November 7, 2019, and entitled “Process for Regenerating Sorbents at High Temperatures,” each of which is incorporated herein by reference in its entirety for all purposes. TECHNICAL FIELD In one aspect, the removal of acid gases that are not carbon dioxide using non-CO₂ acid gas sorbents that include salts in molten form, and related systems and methods, are generally described. In another aspect, processes for regenerating sorbents, and associated systems, are generally described. SUMMARY The removal of acid gases that are not carbon dioxide using non-CO₂ acid gas sorbents that include salts in molten form, and related systems and methods, are generally described. Certain aspects are related to methods. In some embodiments, the method comprises exposing a non-CO₂ acid gas sorbent, the non-CO₂ acid gas sorbent comprising a salt in molten form, to an environment containing a non-CO₂ acid gas such that at least a portion of the non-CO₂ acid gas interacts with the non-CO₂ acid gas sorbent and at least a portion of the non-CO₂ acid gas is removed from the environment. Processes for regenerating sorbents, and associated systems, are also generally described. Certain embodiments are related to the use of steam to remove one or more captured acid gases from the sorbent. Certain aspects are related to methods. In some embodiments, the method comprises regenerating a sorbent that has been exposed to an acid gas via exposure to steam such that at least part of the acid gas is separated from the sorbent. The subject matter of the present invention involves, in some cases, interrelated products, alternative solutions to a particular problem, and/or a plurality of different uses of one or more systems and/or articles. Other advantages and novel features of the present invention will become apparent from the following detailed description of various non-limiting embodiments of the invention when considered in conjunction with the accompanying figures. In cases where the present specification and a document incorporated by reference include conflicting and/or inconsistent disclosure, the present specification shall control. BRIEF DESCRIPTION OF THE DRAWINGS Non-limiting embodiments of the present invention will be described by way of example with reference to the accompanying figures, which are schematic and are not intended to be drawn to scale. In the figures, each identical or nearly identical component illustrated is typically represented by a single numeral. For purposes of clarity, not every component is labeled in every figure, nor is every component of each embodiment of the invention shown where illustration is not necessary to allow those of ordinary skill in the art to understand the invention. FIG.1 is, in accordance with certain embodiments, a schematic diagram of a non-CO₂ acid gas sorbent being exposed to an environment containing non-carbon dioxide acid gas. FIG.2 is, in accordance with certain embodiments, a schematic diagram of a non-CO₂ acid gas sorbent being exposed to an environment containing non-carbon dioxide acid gas that is part of and/or derived from the output of a combustion process. FIGS.3A-3D show, in accordance with some embodiments, the dependence of acid gas concentration on loading for Na_xB_1-xO_1.5-x (x = 0.75) at (A) 600°C, and (B) 700°C, and for (Li_0.5Na_0.5)_xB_1-xO_1.5x (x = 0.75) at (C) 600°C, and (D) 700°C. FIGS.4A-4D show, in accordance with some embodiments, uptake, displacement, and release of acid gas mixtures for Na_xB_1-xO_1.5-x (x = 0.75) at (A) 600°C, and (B) 700°C, and for (Li_0.5Na_0.5)_xB_1-xO_1.5-x (x = 0.75) at (C) 600°C, and (D) 700°C. FIGS.5A-5D show, in accordance with some embodiments, for Na_xB_1-xO_1.5-x (x = 0.75) (A) SO₂ capacity under 5°C/min temperature ramp, isothermal uptake, and predicted by Equations 3 & 4 (B) XRD at 25°C after reaction with SO₂ at 600 °C and 700 °C, for (Li_0.5Na_0.5)_xB_1-xO_1.5-x (x = 0.75) (C) SO₂ capacity under 5°C/min temperature ramp, isothermal uptake, and predicted by (analogous) Equations 3 & 4, and (D) XRD after reaction with SO₂ at 25°C, 600°C, and 700°C. FIGS.6A-6B show, in accordance with some embodiments, (A) H₂S capacity for Na_xB_1-xO_1.5-x (x = 0.75) under 5°C/min temperature ramp, and predicted by Equations 8 & 9 (B) XRD at 25°C after reaction with H₂S at 600°C for Na_xB_1-xO_1.5-x (x = 0.75) and (Li_0.5Na_0.5)_xB_1-xO_1.5- (x = 0.75). FIGS.7A-7D show, in accordance with some embodiments, (A) NO₂ capacity for Na_xB_1-xO_1.5-x (x = 0.75) under 5°C/min temperature ramp, (B) XRD at 25°C after reaction with NO₂ at 600°C and 800°C for Na_xB_1-xO_1.5-x (x = 0.75), (C) Isothermal uptake and release at 600°C for Na_xB_1-xO_1.5-x (x = 0.75), and (D) (Li_0.5Na_0.5)_xB_1-xO_1.5-x (x = 0.75) under 5°C/min temperature ramp. FIG.8 shows a design of a carbon capture system using molten alkali metal borates without consideration for other acid gases separation of sulfurous species at high temperature recovery and purification at ambient temperatures, according to certain embodiments. FIGS.9A-9B are schematic diagrams showing examples of processes of sorbent regeneration, according to some embodiments. FIG.10 is a schematic illustration of a process for regenerating a sorbent coupled with a condenser for condensing steam from a mixture of steam and acid gas, according to certain embodiments. FIG.11A is a schematic diagram showing steam maintained by an energy source internal to the acid gas source, according to certain embodiments. FIG.11B is a schematic diagram showing steam quality maintained by an energy source external to the process that generates the acid gas, according to certain embodiments. FIG.12A is a schematic illustration of the loading of acid gases into a tube furnace, according to some embodiments. FIG.12B depicts a block flow diagram of experimental set-up (bold) and industrial scale design (italics) for high temperature carbon capture using steam as a sweep gas, according to one set of embodiments. FIG.12C shows a schematic illustration of isothermal capture and release of acid gases with multiple cycles, according to one set of embodiments. FIG.12D shows a plot of the dimensionless concentration (e.g., the outlet gas concentration divided by the inlet gas concentration) as function of time with a control and a sample, according to one set of embodiments. FIG.13 is a plot of loading of acid gas within a sorbent as a function of time, according to some embodiments. FIG.14 shows a process schematic for the continuous circulation of sorbent between environments dedicated to capture and release, using steam to drive regeneration in the release environment, according to some embodiments. FIGS.15A-15B show schematics of simplified system level designs for carbon capture based on natural gas combined cycle (NGCC) and steam methane reforming (SMR) with sorption enhanced reforming (SER) designs, according to some embodiments. FIG.16 provides a schematic of detailed system level designs for natural gas combined cycle (NGCC) with carbon capture with additional equipment for the steam sweep process, according to some embodiments. FIG.17 provides a schematic of detailed system level designs for steam methane reforming with sorption enhanced reforming with carbon capture with the additional equipment for the steam sweep process, according to some embodiments. FIG.18 provides a schematic of detailed system level designs for cement production with carbon capture, showing the additional equipment for the steam sweep process, according to some embodiments. DETAILED DESCRIPTION In one aspect, the removal of acid gases that are not carbon dioxide using non-CO₂ acid gas sorbents that include salts in molten form, and related systems and methods, are generally described. In another aspect, processes for regenerating sorbents, and associated systems, are generally described. Treatment of Acid Gases Using Molten Alkali Metal Borates and Associated Methods of Separation The removal of acid gases (including carbon dioxide and acid gases that are not carbon dioxide) from industrial streams may find applications in the energy and chemicals industries, in particular the environmentally responsible production of energy from fossil fuels. Acid gases may be environmental pollutants, as greenhouse gases or producers of acid rain, and in many cases, these acid gases may be severely harmful to human health. Streams often contain multiple acid gases at high temperatures; however, in conventional systems multiple separate low temperature processes are typically deployed in series to treat each acid gas one at a time. A method by which multiple acid gases can be captured and separated at high temperatures, without detrimentally impacting the performance of the system is therefore of keen interest and is described below and elsewhere herein. In certain embodiments, molten alkali metal borates can be used as non-CO₂ acid gas sorbents to remove acid gas(es) that are not CO₂ (also referred to herein as non-CO₂ acid gas(es)) from streams. Certain embodiments are related to the application of molten alkali metal borates in a continuously circulating system for the removal and separation of multiple acid gases at high temperatures. In accordance with certain embodiments, each acid gas interacts differently with the molten alkali metal borates such that each species can be separated from others at distinct points in the high temperature system. In certain embodiments, the product streams are upconentrated at high temperatures either by release as a gas or physical separation of the solids from the recirculating liquid. Certain aspects of the present disclosure are directed to the removal of non-CO₂ acid gases using a non-CO₂ acid gas sorbent that include salt in molten form. In some embodiments, the non-CO₂ acid gas sorbent may act as a sequestration material for one or more non-CO₂ acid gases. In some embodiments, the removal of the non-CO₂ acid gas may occur at an elevated temperature (e.g., at or above the melting temperature of the salt, such that at least the unreacted molten salt remains in molten form). The inventors have appreciated and understood that certain non-CO₂ acid gas sorbents described herein may remove a variety of acid gases, including carbon dioxide. In certain cases, certain non-CO₂ acid gas sorbents may sequester non-CO₂ acid gases. In addition, in some embodiments, certain non-CO₂ acid gas sorbents may preferentially sequester non-CO₂ acid gases over carbon dioxide, which may advantageously be useful in separating carbon dioxide from non- CO₂ acid gases. While much of the disclosure herein is focused on the treatment of non-CO₂ acid gases, it should be understood that the non-CO₂ acid gas sorbents described herein may also sequester (in addition to the non-CO₂ acid gas) carbon dioxide. In accordance with certain embodiments, a non-CO₂ acid gas sorbent may be exposed to an environment containing a non-CO₂ acid gas. A non-CO₂ acid gas is any acid gas that is not carbon dioxide. Non-limiting examples of non-CO₂ acid gases include, sulfur monoxide (SO), sulfur dioxide (SO₂), nitrogen dioxide (NO₂), hydrogen sulfide (H₂S), sulfur trioxide (SO₃), nitric oxide (NO), nitrous oxide (N₂O), dinitrogen trioxide (N₂O₃), dinitrogen tetroxide (N₂O₄), dinitrogen pentoxide (N₂O₅), and/or carbonyl sulfide (COS). Exposure of the non- CO₂ acid gas sorbent to (and removal of) other acid gases is also possible. According to certain embodiments, the non-CO₂ acid gas sorbent is exposed to the non-CO₂ acid gas under conditions favoring sequestration of the non-CO₂ acid gas. For example, in accordance with certain embodiments, a non-CO₂ acid gas sorbent that comprises a salt in molten form can be exposed to the environment containing the non-CO₂ acid gas in a manner facilitating high contact between the two, e.g., the non-CO₂ acid gas sorbent can be flowed (optionally flowed continuously) and/or sprayed during exposure of the non-CO₂ acid gas sorbent to an environment containing the non-CO₂ acid gas. The flowing and/or spraying of the non-CO₂ acid gas sorbent, during exposure of the non-CO₂ acid gas sorbent to an environment containing the non-CO₂ acid gas, may advantageously increase the rate of the non-CO₂ acid gas capture by the non-CO₂ acid gas sorbent relative to the rate of the non-CO₂ acid gas capture by an entirely solid non-CO₂ acid gas sorbent. For example, the non-CO₂ acid gas sorbent comprising a salt in molten form may be flowed and/or sprayed in one direction while an environment comprising the non-CO₂ acid gas is flowed in a different direction, e.g., in the opposite direction, in a crosscurrent or countercurrent type operation to maximize heat and/or mass transfer between the non-CO₂ acid gas sorbent and the environment. Uptake of the non-CO₂ acid gas by a non-CO₂ acid gas sorbent in accordance with the invention can be at any of a variety of desirable levels. Uptake by a non-CO₂ acid gas sorbent comprising a salt in molten form, with the salt including an alkali metal cation and a boron oxide anion and/or a dissociated form thereof, may be as much as or greater than 5 mmol of the non-CO₂ acid gas per gram of non-CO₂ acid gas sorbent within 1 minute of exposure to an environment containing the non-CO₂ acid gas, a significantly faster rate of uptake than for solid particulate non-CO₂ acid gas sorbents of similar composition under similar conditions. In addition, the ability to flow the non-CO₂ acid gas sorbent comprising a salt in molten form facilitates, in accordance with certain embodiments, a continuous sequestration process of non-carbon dioxide acid gas(es), in which a non-CO₂ acid gas-loaded non-CO₂ acid gas sorbent can be flowed from an adsorber vessel to a desorber vessel, and/or an unloaded non-CO₂ acid gas sorbent can be flowed from the desorber vessel to the adsorber vessel, for a plurality of cycles without halting the process. Continuous operation provides, in some embodiments, advantages including but not limited to a reduced duration of a non- CO₂ acid gas capture process, potentially reduced energy input required in the non-CO₂ acid gas capture process, and the ability to refresh poisoned non-CO₂ acid gas sorbent with a purge rather than taking a unit offline. As is described elsewhere herein, a non-CO₂ acid gas or a mixture of non-CO₂ acid gas may also contain at least some carbon dioxide. Certain of the methods described herein may advantageously be used to separate CO₂ from non-CO₂ acid gases and/or one type of non-CO₂ acid gas from other types of non-CO₂ acid gases. Another important advantage associated with the use of a non-CO₂ acid gas sorbent comprising a salt in molten form, in accordance with certain embodiments, is the ability to use the non-CO₂ acid gas sorbent at an elevated temperature, e.g., at a temperature greater than or equal to the melting temperature of the non-CO₂ acid gas sorbent, e.g., greater than or equal to 200 ºC. The temperature can be higher as well, e.g., greater than or equal to 250 °C, greater than or equal to 300 °C, greater than or equal to 350 °C, greater than or equal to 400 °C, greater than or equal to 450 °C, or greater than or equal to 500 ºC, or higher. In some embodiments in which the non-CO₂ acid gas sorbent is used at an elevated temperature, any of a variety of suitable amounts of the non-CO₂ acid gas sorbent (e.g., greater than or equal to 1 wt%, greater than or equal to 10 wt%, greater than or equal to 50 wt%, greater than or equal to 75 wt%, greater than or equal to 90 wt%, greater than or equal to 99 wt%, or all of the non- CO₂ acid gas sorbent) will be at that elevated temperature (e.g., greater than or equal to 200°C, greater than or equal to 250°C, greater than or equal to 300°C, greater than or equal to 350°C, greater than or equal to 400°C, greater than or equal to 450°C, greater than or equal to 500 ºC, and/or within any of the other temperature ranges mentioned above or elsewhere herein). As used herein, temperature of operation refers to the temperature of the non-CO₂ acid gas sorbent itself, which can be essentially equal to or different from the temperature of the environment to which the non-CO₂ acid gas sorbent is exposed. In certain embodiments, the process can optionally take place in a pressure swing operation. Generally, in a pressure swing operation in certain embodiments described herein, the non-CO₂ acid gas sorbent is exposed to an environment having a first partial pressure of non-CO₂ acid gas, during exposure of the non-CO₂ acid gas sorbent to an environment containing the acid gas, and subsequently the non-CO₂ acid gas-loaded non-CO₂ acid gas sorbent is exposed to a second environment having second lower partial pressure of the non- CO₂ acid gas (e.g., 0 bar of the non-CO₂ acid gas), regenerating unloaded non-CO₂ acid gas sorbent. This pressure swing operation may be repeated for a plurality of cycles once the non-CO₂ acid gas sorbent has been regenerated. The first partial pressure of the non-CO₂ acid gas may be, in some embodiments, at least 0.000001 bar, at least 0.0001 bar, at least 0.01 bar, or at least 1 bar. The first partial pressure of the non-CO₂ acid gas may be, in some embodiments, at most 30 bar, at most 20 bar, at most 10 bar, or at most 5 bar. Combinations of the above-referenced ranges are also possible (e.g., between or equal to 0.000001 bar and 30 bar, between or equal to 0.01 bar and 20 bar, between or equal to 0.1 bar and 10 bar, between or equal to 1 bar and 5 bar). Other ranges are also possible. The second partial pressure of the non-CO₂ acid gas may be, in some embodiments, less than the first partial pressure of the non-CO₂ acid gas by at least 0.000001 bar, at least 0.0001 bar, at least 0.01 bar, or at least 1 bar. The second partial pressure of the non-CO₂ acid gas may be, in some embodiments, less than the first partial pressure of the non-CO₂ acid gas by at most 30 bar, at most 20 bar, at most 10 bar, or at most 5 bar. Combinations of the above-referenced ranges are also possible (e.g., between or equal to 0.001 bar and 30 bar less, between or equal to 0.01 bar and 20 bar less, between or equal to 0.1 bar and 10 bar less, between or equal to 1 bar and 5 bar less). Other ranges are also possible. The process can optionally take place in a temperature swing operation. Generally in a temperature swing operation, in accordance with certain embodiments described herein, the non-CO₂ acid gas sorbent is exposed to a first temperature, during exposure of the non-CO₂ acid gas sorbent to an environment containing non-CO₂ acid gas, and subsequently the non- CO₂ acid gas loaded non-CO₂ acid gas sorbent is exposed to a second higher temperature in a second environment containing less or no non-CO₂ acid gas, regenerating unloaded non-CO₂ acid gas sorbent. This temperature swing operation may be repeated for a plurality of cycles once the non-CO₂ acid gas sorbent has been regenerated. The first temperature may be greater than or equal to the melting temperature of the non-CO₂ acid gas sorbent, e.g., greater than or equal to 200 ºC. The first temperature can be higher as well, e.g., greater than or equal to 250°C, greater than or equal to 300°C, greater than or equal to 350°C, greater than or equal to 400°C, greater than or equal to 450°C, or greater than or equal to 500 ºC or higher, and/or less than or equal to 1000 ºC. In some embodiments, the second temperature is equal to the first temperature. The second temperature may be, in some embodiments, greater than the first temperature by at least 10°C, at least 50°C, at least 100°C, at least 200°C, at least 300°C, at least 400°C, or at least 500°C. The second temperature may be, in some embodiments, greater than the first temperature by at most 1000°C, at most 900°C, at most 800°C, at most 700°C, or at most 600°C. Combinations of the above-referenced ranges are also possible (e.g., between or equal to 10°C and 300°C greater, between or equal to 200°C and 400°C greater, between or equal to 400°C and 1000°C greater). Other ranges are also possible. It is noted that unless specified otherwise, temperatures and other conditions described herein are at approximately atmospheric pressure, although deviation from atmospheric pressure can occur while still meeting the objectives of the invention. Those of ordinary skill can select different pressures to achieve the results outlined herein. Certain embodiments are related to a non-CO₂ acid gas sorbent material. As used herein, the phrase “non-CO₂ acid gas sorbent” is used to describe a material that is capable of removing non-CO₂ acid gas (optionally along with CO₂) from an environment containing non-CO₂ acid gas. In some embodiments, the non-CO₂ acid gas sorbent may function as a sequestration material. Certain aspects are related to a non-CO₂ acid gas sorbent that comprises a salt in molten form, the composition of which salt can be selected to have a low melting temperature relative to other salts such that less energy is required to melt the salt. In addition, the composition of the salt can be selected in order to tune the melting point (e.g., melting temperature at 1 atm) of the salt, e.g., to approach or match the temperature at which the non- CO₂ acid gas, to which the salt is exposed, is emitted from a source of non-CO₂ acid gas. In certain embodiments, the salt is in molten form. For example, in some embodiments, a solid salt comprising an alkali metal cation and a boron oxide anion (and/or a dissociated form thereof) can be heated above its melting temperature which results in the solid transitioning into a liquid state. According to certain embodiments, the salt comprising an alkali metal cation and a boron oxide anion (and/or a dissociated form thereof) is a salt having a melting point between or equal to 200 ºC and 1000 ºC (or between 200 °C and 700 °C) when at atmospheric pressure. Those of ordinary skill in the art would understand that a molten salt is different from a solubilized salt (i.e., a salt that has been dissolved within a solvent). The salt in molten form can have a number of chemical compositions. According to certain embodiments, the salt in molten form comprises at least one alkali metal cation and at least one boron oxide anion and/or a dissociated form thereof. The term “alkali metal” is used herein to refer to the following six chemical elements of Group 1 of the periodic table: lithium (Li), sodium (Na), potassium (K), rubidium (Rb), cesium (Cs), and francium (Fr). In some embodiments, the at least one alkali metal cation comprises cationic lithium (Li), sodium (Na), potassium (K), rubidium (Rb), and/or cesium (Cs). In some embodiments, the at least one alkali metal cation comprises cationic lithium (Li), sodium (Na), and/or potassium (K). In some embodiments, the salt in molten form comprises at least one other metal cation. In some embodiments, the at least one other metal cation comprises an alkali metal cation, an alkaline earth metal cation, or a transition metal cation. In some embodiments, the salt in molten form comprises at least two alkali metal cations (e.g., 3 alkali metal cations). In certain embodiments, the salt in molten form comprises cationic lithium and cationic sodium. A salt in molten form comprising cationic lithium and cationic sodium may in some embodiments provide advantages in a temperature swing operation, e.g., relative to an analogous salt in molten form comprising cationic sodium or an analogous salt in molten form comprising cationic lithium, cationic sodium, and cationic potassium. One advantage of a salt in molten form comprising cationic lithium and cationic sodium may be a higher uptake capacity of non-CO₂ acid gas, in a temperature range of between or equal to 500°C and 700°C, than an analogous salt in molten form comprising cationic sodium or an analogous salt in molten form comprising cationic lithium, cationic sodium, and cationic potassium. Another advantage of a salt in molten form comprising cationic lithium and cationic sodium may be that a lesser temperature difference can be employed in a temperature swing operation for the same regeneration efficiency of the capture and release of non-CO₂ acid gas (e.g., a temperature difference of between or equal to 0.25 and 0.5 times the temperature difference employed for analogous salts) relative to an analogous salt in molten form comprising cationic sodium or an analogous salt in molten form comprising cationic lithium, cationic sodium, and cationic potassium. The term “alkaline earth metal” is used herein to refer to the six chemical elements in Group 2 of the periodic table: beryllium (Be), magnesium (Mg), calcium (Ca), strontium (Sr), barium (Ba), and radium (Ra). The “transition metal” elements are scandium (Sc), yttrium (Y), lanthanum (La), actinium (Ac), titanium (Ti), zirconium (Zr), hafnium (Hf), rutherfordium (Rf), vanadium (V), niobium (Nb), tantalum (Ta), dubnium (Db), chromium (Cr), molybdenum (Mo), tungsten (W), seaborgium (Sg), manganese (Mn), technetium (Tc), rhenium (Re), bohrium (Bh), iron (Fe), ruthenium (Ru), osmium (Os), hassium (Hs), cobalt (Co), rhodium (Rh), iridium (Ir), meitnerium (Mt), nickel (Ni), palladium (Pd), platinum (Pt), darmstadtium (Ds), copper (Cu), silver (Ag), gold (Au), roentgenium (Rg), zinc (Zn), cadmium (Cd), mercury (Hg), and copernicium (Cn). In certain embodiments, it may be advantageous for the salt in molten form to comprise an alkali metal cation and one other metal cation at a composition at or near a eutectic composition, such that the melting temperature of the salt is lower than the melting temperature of a salt with a different composition of the alkali metal cation and the one other metal cation, reducing the energy required to attain the salt in molten form for an operation for the sequestration of non-CO₂ acid gas(es). Certain of the non-CO₂ acid gas sorbents described herein have relatively low melting temperatures and may promote sequestration (e.g., absorption) of non-CO₂ acid gas at relatively low temperatures. For example, components that are capable of forming eutectic compositions with each other have reduced melting points at the eutectic composition and at compositions surrounding the eutectic composition in comparison to compositions in which the components are present in other relative amounts. As another example, compositions comprising alkali metal cations and/or alkaline earth metal cations have relatively low melting points in comparison to compositions comprising other metal cations. The ability to absorb non-CO₂ acid gas at relatively low temperatures can be advantageous as it may, according to certain although not necessarily all embodiments, reduce the amount of energy required to absorb acid gases. In some embodiments the non-CO₂ acid gas sorbent comprises at least two components (e.g., metal cations, alkali metal cation(s)) that are capable of forming a eutectic composition with each other. As would be understood by one of ordinary skill in the art, a “eutectic composition” is a composition that melts at a temperature lower than the melting points of the composition’s constituents. In some eutectic compositions, the liquid phase is in equilibrium with both a first solid phase and a second solid phase different from the first solid phase at the eutectic temperature. A eutectic composition that is cooled from a temperature above the eutectic temperature to a temperature below the eutectic temperature under equilibrium cooling conditions undergoes, in certain cases, solidification at the eutectic temperature to form a first solid phase and a second solid phase simultaneously from a liquid. As would also be understood by one of ordinary skill in the art, two components that are capable of forming a eutectic composition with each other are, in certain cases, also able to form non-eutectic compositions with each other. Non-eutectic compositions often undergo solidification over a range of temperatures because liquid phases may be in equilibrium with solid phases over a range of temperatures. The term “boron oxide anion” is used herein to refer to a negatively charged ion comprising at least one boron and at least one oxygen. The boron oxide anion in the salt in molten form can be intact (e.g., in anionic BwOz form, e.g., (BO₃ ^3-)) and/or the boron and oxygen can be dissociated from one another (e.g., into boron cation(s) and oxygen anion(s), e.g., as B³⁺ and O^2-). According to some embodiments, the at least one boron oxide anion comprises anionic BwOz and/or a dissociated form thereof. In some embodiments, w is greater than 0 and less than or equal to 4. In certain embodiments, w is between or equal to 1 and 4. In some embodiments, z is greater than 0 and less than or equal to 9. In certain embodiments, z is between or equal to 1 and 9. In some embodiments, the at least one boron oxide anion comprises anionic BO₃, BO₄, or B₂O₅ and/or a dissociated form thereof. In certain embodiments, it may be advantageous to have a salt in molten form comprise anionic BO₃ and/or a dissociated form thereof. A potential advantage of anionic BO₃ and/or a dissociated form thereof may include a greater acid gas uptake capacity of the salt in molten form during exposure to an environment containing acid gas, relative to a salt having the same alkali metal cation (and any other cations) and anionic B₂O₅ and/or a dissociated form thereof. Another potential advantage of anionic BO₃ and/or a dissociated form thereof may include a greater acid gas desorption of the salt in molten form during exposure to desorption conditions, relative to a salt having the same alkali metal cation (and any other cations) and anionic BO₄ and/or a dissociated form thereof. In some embodiments, the boron oxide anion comprises B_wO_z and/or a dissociated form thereof, wherein w is greater than 0 and less than or equal to 4 and z is greater than 0 and less than or equal to 9. In some embodiments, the fractional stoichiometry of a salt described herein can be expressed as MxB1-xOy, wherein x is a mixing ratio and is between zero and 1. In some embodiments, the fractional stoichiometry is that of the salt in solid form, e.g., before melting. In some embodiments, the fractional stoichiometry is that of the salt in molten form, e.g., after melting. In certain embodiments, y = 1.5 – x. “M” in this formula refers to the metal cation(s) (e.g., an alkali metal cation, a combination of an alkali metal cation and at least one other metal cation) in a non-CO₂ acid gas sorbent described herein. For example, in some embodiments, the fractional stoichiometry of a salt described herein can be expressed as A_xB_1-xO_y, where 0 < x < 1 and A is an alkali metal (e.g., Li, Na, K). In certain such embodiments, y = 1.5 – x. As used herein, the term “mixing ratio” of an alkali metal cation or combination of metal cations in a non-CO₂ acid gas sorbent refers to the ratio of moles of metal cation(s) in a non-CO₂ acid gas sorbent to the total of moles of metal cation(s) plus moles of boron in the non-CO₂ acid gas sorbent. For example, the mixing ratio of sodium in Na₃BO₃ is 3/(3+1) = 0.75; the mixing ratio of alkali metals in (Li0.5Na0.5)3BO₃ is (0.5*3 + 0.5*3)/(3+1) = 0.75. In some embodiments, the mixing ratio is at least 0.5, at least 0.6, or at least 0.667. In some embodiments, the mixing ratio is at most 0.9, at most 0.835, at most 0.8, at most 0.75, or at most 0.7. Combinations of the above-referenced ranges are also possible (e.g., between or equal to 0.5 and 0.9, between or equal to 0.6 and 0.8, between or equal to 0.7 and 0.8). Other ranges are also possible. Without wishing to be bound by theory, there may be a mixing ratio (for a certain alkali metal cation or combination of metal cations) below which the acid gas uptake capacity of the non-CO₂ acid gas sorbent is less than desirable. Without wishing to be bound by theory, there may be a mixing ratio (for a certain alkali metal cation or combination of metal cations) above which the regeneration efficiency of the non-CO₂ acid gas sorbent is less than desirable. In some embodiments, the alkali metal comprises lithium (Li), sodium (Na), potassium (K), and/or a mixture of these. In some embodiments, the alkali metal comprises Li and Na in equal amounts. Non-limiting examples of the salt in molten form include but are not limited to Na₃BO₃ (which could also be written as, e.g., Na_0.75B_0.25O_0.75), Na₅BO₄ (which could also be written as, e.g., Na_0.83B_0.17O_0.67), Na₄B₂O₅ (which could also be written as, e.g., Na₂BO_2.5), K₃BO₃ (which could also be written as, e.g., K_0.75B_0.25O_0.75), (Li_0.5Na_0.5)₃BO₃, and/or (Li_0.33Na_0.33K_0.33)₃BO₃, or a combination thereof, in molten form. In some embodiments, the salt of the non-CO₂ acid gas sorbent that is in molten form may be accompanied by portions of that salt that are not molten. That is to say, complete melting of all of the salt type(s) that are present in molten form is not required in all embodiments. In some embodiments, at least 10 wt%, at least 20 wt%, at least 30 wt%, at least 40 wt%, at least 50 wt%, at least 60 wt%, at least 70 wt%, at least 80 wt%, at least 90 wt%, or more of the salt present within the non-CO₂ acid gas sorbent is molten. In some embodiments, less than 100 wt%, less than 99 wt%, less than 90 wt%, or less of the salt that is present within the non-CO₂ acid gas sorbent is molten. Combinations of the above- referenced ranges are also possible (e.g., at least 10 wt% and less than 100 wt%). Other ranges are also possible. In some embodiments, the non-CO₂ acid gas sorbent comprises at least one salt comprising at least one alkali metal cation and at least one boron oxide anion and/or a dissociated form thereof (e.g., including, but not limited to, Na₃BO₃, Na₅BO₄, Na₄B₂O₅, K₃BO₃, (Li_0.5Na_0.5)₃BO₃, and/or (Li_0.33Na_0.33K_0.33)₃BO₃) for which at least 10 wt%, at least 20 wt%, at least 30 wt%, at least 40 wt%, at least 50 wt%, at least 60 wt%, at least 70 wt%, at least 80 wt%, at least 90 wt%, or more of that salt is molten. In some embodiments, the non- CO₂ acid gas sorbent comprises at least one salt comprising at least one alkali metal cation and at least one boron oxide anion and/or a dissociated form thereof (e.g., including, but not limited to, Na₃BO₃, Na₅BO₄, Na₄B₂O₅, K₃BO₃, (Li_0.5Na_0.5)₃BO₃, and/or (Li_0.33Na_0.33K_0.33)₃BO₃) for which less than 100 wt%, less than 99 wt%, less than 90 wt%, or less of that salt is molten. Combinations of the above-referenced ranges are also possible. Other ranges are also possible. In some embodiments, in the non-CO₂ acid gas sorbent, the total amount of all salts that comprise at least one alkali metal cation and at least one boron oxide anion and/or a dissociated form thereof and that is in molten form is at least 10 wt%, at least 20 wt%, at least 30 wt%, at least 40 wt%, at least 50 wt%, at least 60 wt%, at least 70 wt%, at least 80 wt%, at least 90 wt%, or more. As a non-limiting exemplary illustration, in some embodiments, the non-CO₂ acid gas sorbent can be a combination of 50 grams of Na₃BO₃, 50 grams of Na₅BO₄, and 50 grams of Na₄B₂O₅, and in some such embodiments, at least 15 grams (i.e., 10 wt% of 150 total grams) of the total amount of Na3BO₃, Na5BO₄, and Na4B₂O₅ is molten. In certain embodiments, in the non-CO₂ acid gas sorbent, the total amount of all salts that comprise at least one alkali metal cation and at least one boron oxide anion and/or a dissociated form thereof and that is in molten form is less than 100 wt%, less than 99 wt%, less than 90 wt%, less than 50%, less than 40%, less than 30%, less than 20%, or less. Combinations of the above-referenced ranges are also possible (e.g., at least 10 wt% and less than 100 wt%). Other ranges are also possible. In some embodiments, a non-CO₂ acid gas sorbent further comprises an additive. Examples of types of additives that may be included in a non-CO₂ acid gas sorbent include but are not limited to corrosion inhibitors, viscosity modifiers, wetting agents, high- temperature surfactants, and scale inhibitors. In some embodiments, the non-CO₂ acid gas sorbent comprises a plurality of additives (e.g., two, three, four, or more). In some embodiments, during exposure to an environment comprising a non-CO₂ acid gas, at least a portion of the salt in molten form chemically reacts with at least some of the non-CO₂ acid gas and forms one or more products (e.g., comprising a carbonate, comprising nitrate, comprising nitrite, comprising sulfate, comprising sulfite) within the non-CO₂ acid gas sorbent. These one or more products (e.g., carbonate products, nitrate products, nitrate products, sulfate products, sulfite products) may be in solid form or in liquid form, depending, e.g., on the temperature and/or composition of the salt (e.g., alkali metal borate salt). In some embodiments, during exposure to an environment comprising non-CO₂ acid gas, at least a portion of the salt in molten form chemically reacts with at least some of the non-CO₂ acid gas(es) and forms solid particles (e.g., comprising a carbonate, a sulfate, a sulfite, a nitrate, a nitrite) within the non-CO₂ acid gas sorbent, increasing the viscosity of the non-CO₂ acid gas sorbent. These solid particles loaded with non-CO₂ acid gas(es) may be flowed within remaining salt in molten form using a slurry pump to a desorber to be regenerated (e.g., regeneration of salt in molten form from the solid particulates), or alternatively these solid particles may be regenerated within the same vessel in which the solid particles were formed. In some embodiments, a relatively large percentage of the non-CO₂ acid gas sorbent is made up of a salt in molten form. For example, in some embodiments, at least 10 weight percent (wt%), at least 20 wt%, at least 30 wt%, at least 40 wt%, at least 50 wt%, at least 60 wt%, at least 70 wt%, at least 80 wt%, at least 90 wt%, or more of the non-CO₂ acid gas sorbent is made up of a salt in molten form. In some embodiments, at most 100 wt%, at most 99 wt%, or at most 90 wt% of the non-CO₂ acid gas sorbent is made up of a salt in molten form. Combinations of the above-referenced ranges are also possible (e.g., between or equal to 10 wt% and 100 wt%, between or equal to 20 wt% and 99 wt%, between or equal to 50 wt% and 90 wt%). Other ranges are also possible. In some embodiments, all of the non-CO₂ acid gas sorbent is molten. In other embodiments, only a portion of the non-CO₂ acid gas sorbent is molten. In some embodiments, a relatively large percentage of the non-CO₂ acid gas sorbent is chemically converted to non-CO₂ acid gas-loaded solid particles during sequestration (e.g., absorption). For example, in some embodiments, at least 1 wt%, at least 10 wt%, or at least 20 wt% of the non-CO₂ acid gas sorbent is made up of non-CO₂ acid gas-loaded solid particles. In some embodiments, at most 90 wt%, at most 80 wt%, or at most 50 wt% of the non-CO₂ acid gas sorbent is made up of non-CO₂ acid gas-loaded solid particles. Combinations of the above-referenced ranges are also possible (e.g., between or equal to 1 wt% and 90 wt%, between or equal to 10 wt% and 80 wt%, between or equal to 10 wt% and 50 wt%, between or equal to 20 wt% and 50 wt%). Other ranges are also possible. In some embodiments, the non-CO₂ acid gas sorbent also comprises a hydroxide of an alkali metal. For example, in some embodiments, the non-CO₂ acid gas sorbent comprises NaOH, KOH, and/or LiOH. According to certain embodiments, a hydroxide of an alkali metal can be formed as a by-product of a reaction between the non-CO₂ acid gas sorbent and a non-CO₂ acid gas. According to certain embodiments, the non-CO₂ acid gas sorbent is capable of interacting with a non-CO₂ acid gas such that a relatively large amount of the non-CO₂ acid gas is sequestered. In certain embodiments, the non-CO₂ acid gas sorbent is capable of interaction with mixtures of non-CO₂ acid gases. In some embodiments, the non-CO₂ acid gas sorbent may preferentially sequester non-CO₂ acid gas(es) over CO₂, and thus may facilitate the separation of non-CO₂ acid gases from CO₂. Interaction between the non-CO₂ acid gas sorbent and acid gases (e.g., non-CO₂ acid gases) can involve a chemical reaction, adsorption, and/or diffusion. In some embodiments, a plurality of non-CO₂ acid gases interacts with the non-CO₂ acid gas sorbent such that at least a portion of the plurality of non- CO₂ acid gases are removed from the environment. For example, in certain embodiments, the non-CO₂ acid gas sorbent is capable of interacting with a non-CO₂ acid gas such that at least 0.01 mmol of the non-CO₂ acid gas is sequestered (e.g., from an environment, e.g., from an atmosphere, from a stream) per gram of the non-CO₂ acid gas sorbent. In some embodiments, the non-CO₂ acid gas sorbent is capable of interacting with a non-CO₂ acid gas such that at least 0.1 mmol, at least 0.5mmol, at least 2.0 mmol, or at least 10.0 mmol of the non-CO₂ acid gas is sequestered (e.g., from an environment, e.g., from an atmosphere, from a stream) per gram of the non-CO₂ acid gas sorbent. In certain embodiments, the non-CO₂ acid gas sorbent is capable of interacting with the non-CO₂ acid gas such that at most 20.0 mmol, at most 18.0 mmol, at most 16.0 mmol, at most 14.0 mmol, or at most 12.0 mmol of the acid gas is sequestered (e.g., from an environment, e.g., from an atmosphere, from a stream) per gram of the non-CO₂ acid gas sorbent. Combinations of the above-referenced ranges are also possible (e.g., between or equal to 0.1 mmol per gram and 20.0 mmol per gram, between or equal to 0.5 mmol per gram and 16.0 mmol per gram, between or equal to 2.0 mmol per gram and 12.0 mmol per gram). According to certain embodiments, the non-CO₂ acid gas sorbent is capable of interacting with the non-CO₂ acid gas such that a relatively large amount of the non-CO₂ acid gas is sequestered even when the non-CO₂ acid gas concentration in the environment (e.g., in an atmosphere, in a stream) is relatively low. For example, in some embodiments, the non- CO₂ acid gas sorbent is capable of sequestering at least 0.01 mmol, at least 0.1 mmol, at least 0.5 mmol, at least 2.0 mmol, at least 10.0 mmol and/or at most 20.0 mmol, at most 18.0 mmol, at most 16.0 mmol, at most 14.0 mmol, or at most 12.0 mmol of the non-CO₂ acid gas per gram of the non-CO₂ acid gas sorbent when the non-CO₂ acid gas sorbent is exposed to a steady state environment containing as little as 50 mol%, as little as 25 mol%, as little as 10 mol%, or as little as 1 mol% of the non-CO₂ acid gas (e.g., with the balance of the environment being argon). According to certain embodiments, the non-CO₂ acid gas sorbent is capable of interacting with a non-CO₂ acid gas such that a relatively large amount of the non-CO₂ acid gas is sequestered even at relatively low temperatures. For example, in some embodiments, the non-CO₂ acid gas sorbent is capable of sequestering at least 0.01 mmol, at least 0.1 mmol, at least 0.5 mmol, at least 2.0 mmol, at least 10.0 mmol and/or at most 20.0 mmol, at most 18.0 mmol, at most 16.0 mmol, at most 14.0 mmol, or at most 12.0 mmol of the non-CO₂ acid gas per gram of the non-CO₂ acid gas sorbent when the non-CO₂ acid gas sorbent is at a temperature of 1000 °C or less, at a temperature of 850 °C or less, at a temperature of 600 °C or less, at a temperature of 550 °C or less, or at a temperature of 520 °C or less (and/or, at a temperature of at least 200 °C, at least 300 °C, at least 400 °C, at least 450 °C, or at least 500°C). Combinations of the above-referenced ranges are also possible (e.g., between or equal to 200°C and 1000°C, between or equal to 200°C and 600°C, between or equal to 400°C and 550°C). Other ranges are also possible. According to certain embodiments, the salt of the non-CO₂ acid gas sorbent has a melting temperature at 1 atm within a range high enough to provide a high rate of sequestration of the non-CO₂ acid gas(es), but not so high as to make the sequestration of the non-CO₂ acid gas(es) an overly energy-intensive process. In some embodiments, the salt of the non-CO₂ acid gas sorbent has a melting temperature at 1 atm of at least 200 °C, at least 300 °C, at least 400 °C, at least 450 °C, or at least 500°C. In some embodiments, the salt of the non-CO₂ acid gas sorbent has a melting temperature at 1 atm of at most 1000 °C, at most 850 °C, at most 600 °C, at most 550 °C, or at most 520 °C. Combinations of the above- referenced ranges are also possible (e.g., between or equal to 200°C and 1000 °C, between or equal to 200°C and 600°C, between or equal to 400°C and 550°C). Other ranges are also possible. According to certain embodiments, the non-CO₂ acid gas sorbent is capable of interacting with a non-CO₂ acid gas such that a relatively large amount of the non-CO₂ acid gas is sequestered over a relatively short period of time. For example, in some embodiments, the non-CO₂ acid gas sorbent is capable of sequestering at least 0.01 mmol, at least 0.1 mmol, at least 0.5 mmol, at least 2.0 mmol, at least 10.0 mmol and/or at most 20.0 mmol, at most 18.0 mmol, at most 16.0 mmol, at most 14.0 mmol, or at most 12.0 mmol of the non-CO₂ acid gas per gram of the non-CO₂ acid gas sorbent when the non-CO₂ acid gas sorbent is exposed to an environment containing the non-CO₂ acid gas for a period of 24 hours or less, 12 hours or less, 8 hours or less, 4 hours or less, 1 hour or less, 30 minutes or less, 10 minutes or less, or 2 minutes or less (and/or, at least 10 seconds, at least 20 seconds, at least 30 seconds, or at least 1 minute). Combinations of the above-referenced ranges are also possible (e.g., between or equal to 10 seconds and 24 hours, between or equal to 20 seconds and 12 hours, between or equal to 30 seconds and 8 hours, between or equal to 1 minute and 4 hours, between or equal to 1 minute and 10 minutes, between or equal to 1 minute and 2 minutes). Other ranges are also possible. The amount of non-CO₂ acid gas sequestered by a non-CO₂ acid gas sorbent can be determined, for example, using thermogravimetric analysis. In addition to non-CO₂ acid gas sorbents, methods of capturing non-CO₂ acid gas using non-CO₂ acid gas sorbents are also described. For example, certain of the non-CO₂ acid gas sorbents described herein can be used to remove non-CO₂ acid gas from a chemical process stream (e.g., the exhaust stream of a combustion system) and/or from an environment containing non-CO₂ acid gas (e.g., an environment within a reactor or other unit operation). In some embodiments, a method comprises melting a solid non-CO₂ acid gas sorbent comprising a salt described herein (e.g., an alkali metal borate), and using the molten non- CO₂ acid gas sorbent to sequester a non-CO₂ acid gas. In some embodiments, the salt (e.g., alkali metal borate) in molten form comprises an alkali metal cation, a boron oxide anion, a boron cation, and/or an oxygen anion. In certain embodiments, all of these species are present in the salt in molten form. In some embodiments, the salt (e.g., alkali metal borate) in molten form comprises an alkali metal cation, a boron cation, and an oxygen anion. Certain aspects are related to methods of sequestering a non-CO₂ acid gas using a non-CO₂ acid gas sorbent described herein. Certain aspects are directed to a method comprising exposing a non-CO₂ acid gas sorbent described herein to an environment containing the non-CO₂ acid gas such that at least some of the non-CO₂ acid gas interacts with the non-CO₂ acid gas sorbent and at least a portion of the non-CO₂ acid gas is sequestered from the environment. In some such embodiments, a relatively large percentage of the non-CO₂ acid gas (e.g., at least 25 wt%, at least 50 wt%, at least 75 wt%, at least 90 wt%, at least 95 wt%, at least 99 wt%, at least 99.9 wt%, or more of the non-CO₂ acid gas) is removed from the environment. In certain embodiments, essentially all of the non-CO₂ acid gas is removed from the environment. In certain embodiments, a method comprises exposing a non-CO₂ acid gas sorbent at a temperature of at least 200 ºC to an environment containing non-CO₂ acid gas such that at least some of the non-CO₂ acid gas interacts with the non-CO₂ acid gas sorbent and is sequestered from the environment. The non-CO₂ acid gas sorbent can be exposed to an environment containing a non- CO₂ acid gas in a number of ways. For example, in some embodiments, the non-CO₂ acid gas sorbent can be added to an environment (e.g., an atmosphere, a stream) containing the non-CO₂ acid gas. According to certain embodiments, the environment containing the non- CO₂ acid gas can be transported into (e.g., flowed through) a container holding the non-CO₂ acid gas sorbent. In certain embodiments, the non-CO₂ acid gas sorbent comprising a salt in molten form can be flowed or sprayed through a container in which the environment resides and/or is flowed in the same and/or opposite direction to the flow direction or spray direction of the non-CO₂ acid gas sorbent. Combinations of these methods are also possible. The non- CO₂ acid gas to which the non-CO₂ acid gas sorbent is exposed is generally in fluidic form (e.g., in the form of a gas and/or a supercritical fluid). In certain embodiments, at least a portion of the non-CO₂ acid gas to which the non-CO₂ acid gas sorbent is exposed is in the form of a subcritical gas. The environment containing a non-CO₂ acid gas to which the non-CO₂ acid gas sorbent is exposed can be, for example, contained within a chemical processing unit operation. Non-limiting examples of such unit operations include reactors (e.g., packed bed reactors, fluidized bed reactors, falling film columns, bubble columns), separators (e.g., particulate filters, such as diesel particulate filters), and mixers. According to certain embodiments, the environment containing the non-CO₂ acid gas is contained within a falling film column. According to certain embodiments, the environment containing the non-CO₂ acid gas is part of and/or derived from the output of a combustion process. In certain embodiments, a method comprises exposing the non-CO₂ acid gas sorbent to a stream containing a non-CO₂ acid gas (optionally also containing CO₂). FIG.1 is, in accordance with certain embodiments, a schematic diagram of a non-CO₂ acid gas sorbent being exposed to an environment containing non-CO₂ acid gas. As shown in FIG.1, method 100a may comprise exposing non-CO₂ acid gas sorbent 102 to stream 104a containing non- CO₂ acid gas. The stream to which the non-CO₂ acid gas sorbent is exposed can be, for example, part of and/or derived from a stream of a chemical process containing non-CO₂ acid gas. For example, in some embodiments, the stream to which the non-CO₂ acid gas sorbent is exposed can be part of and/or derived from an output (e.g., an exhaust stream) of a combustion process. FIG.2 is, in accordance with certain embodiments, a schematic diagram of a non-CO₂ acid gas sorbent being exposed to an environment containing a non-CO₂ acid gas that is part of and/or derived from the output of a combustion process. As shown in FIG. 2, method 100b may comprise exposing non-CO₂ acid gas sorbent 102 to stream 104b containing the non-CO₂ acid gas that is part of and/or derived from the output of combustion process 108. In some embodiments, at least a portion of an output stream of a combustion process is directly transported through the non-CO₂ acid gas sorbent. For example, as shown in FIG 2, at least a portion of stream 104b of combustion process 108 is directly transported through non-CO₂ acid gas sorbent 102. The stream to which the non-CO₂ acid gas sorbent is exposed can be, for example, transported through a chemical processing unit operation. Non-limiting examples of such unit operations include reactors (e.g., packed bed reactors, fluidized bed reactors, falling film columns, bubble columns), separators (e.g., particulate filters, such as diesel particulate filters), and mixers. For example, referring back to FIG. 1, in some embodiments, non-CO₂ acid gas sorbent 102 is located within optional reactor 110. According to certain embodiments, the stream to which the non-CO₂ acid gas sorbent is exposed is transported through a falling film column. The non-CO₂ acid gas sorbents described herein can be used to remove non-CO₂ acid gas generated by a variety of systems. For example, in some embodiments, the non-CO₂ acid gas sorbent is used to remove non-CO₂ acid gas from an exhaust stream from a boiler (e.g., in a power plant), from an exhaust stream from an integrated gasification combined cycle (IGCC) power plant, from an exhaust stream from an internal combustion engine (e.g., from a motor vehicle), from an exhaust stream from a pyro-processing furnace (e.g., as used in the cement industry), and/or from a stream from a hydrogen generation process (e.g., by sorption enhanced steam reforming (SESR)). The concentration of non-CO₂ acid gas in the fluid to which the non-CO₂ acid gas sorbent is exposed can be within a variety of ranges. In some embodiments, the environment (e.g., an atmosphere, a stream) to which the non-CO₂ acid gas sorbent is exposed contains non-CO₂ acid gas in an amount of at least 1 ppm. In certain embodiments, the environment (e.g., an atmosphere, a stream) to which the non-CO₂ acid gas sorbent is exposed contains non-CO₂ acid gas in an amount of at least 10 ppm, at least 1000 ppm, at least 0.01 mol%, at least 0.1 mol%, at least 1 mol%, at least 10 mol%, at least 50 mol%, or at least 99 mol%. The non-CO₂ acid gas sorbent can be exposed, in some embodiments, to essentially pure non- CO₂ acid gas. In some embodiments, a method involves exposing the non-CO₂ acid gas sorbent to an environment that contains non-CO₂ acid gas in an amount of at least 1 ppm. Certain embodiments comprise exposing the non-CO₂ acid gas sorbent to an environment (e.g., an atmosphere, a stream) comprising non-CO₂ acid gas such that at least a portion of the non-CO₂ acid gas interacts with the non-CO₂ acid gas sorbent and at least a portion of the non-CO₂ acid gas is sequestered from the environment (e.g., from the atmosphere, from the stream). For example, as shown in FIG.1, at least a portion of the non- CO₂ acid gas in stream 104a interacts with non-CO₂ acid gas sorbent 102 and is sequestered from stream 104a, thereby being absent from stream 106a. In certain embodiments, stream 106a may contain less non-CO₂ acid gas than stream 104a after at least a portion of the non- CO₂ acid gas in stream 104a interacts with non-CO₂ acid gas sorbent 102 and is sequestered from stream 104a. The interaction between the non-CO₂ acid gas that is sequestered and the non-CO₂ acid gas sorbent can take a variety of forms. For example, in certain embodiments, the non-CO₂ acid gas is absorbed into the non-CO₂ acid gas sorbent. In some embodiments, the non-CO₂ acid gas is adsorbed onto the non-CO₂ acid gas sorbent. In some embodiments, the non-CO₂ acid gas chemically reacts with the non-CO₂ acid gas sorbent. In some embodiments, the non-CO₂ acid gas diffuses into the non-CO₂ acid gas sorbent. Combinations of two or more of these mechanisms (i.e., absorption, adsorption, chemical reaction, and/or diffusion) are also possible. In some embodiments, sequestration of the CO₂ does not produce a solid precipitant. In some embodiments, captured non-CO₂ acid gas forms a solid suspended in the liquid non-CO₂ acid gas sorbent and is upconcentrated by physical separation. In some embodiments, the physical separation uses a cross-flow filter. In some embodiments, the cross-flow filter is operated at a temperature of at least 200 ºC (or at least 400 °C, at least 600 °C, or at least 800 ºC). In some embodiments, the cross-flow filter is operated at a temperature of no greater than 1000 ºC. In some embodiments, the separation comprises centrifugation. In certain embodiments, the separation comprises crystallization. In some embodiments, the separation comprises sedimentation. Combinations of these are also possible. According to certain embodiments, a relatively large amount of a non-CO₂ acid gas is sequestered by the non-CO₂ acid gas sorbent (e.g., from an atmosphere, from a stream) during the exposure of the non-CO₂ acid gas sorbent to the non-CO₂ acid gas. For example, in certain embodiments, at least 0.01 mmol of the non-CO₂ acid gas is sequestered (e.g., from an environment, e.g., from an atmosphere, from a stream) per gram of the non-CO₂ acid gas sorbent. In some embodiments, at least 0.1 mmol, at least 0.5 mmol, at least 2.0 mmol, or at least 10.0 mmol of the non-CO₂ acid gas is sequestered (e.g., from an environment, e.g., from an atmosphere, from a stream) per gram of the non-CO₂ acid gas sorbent. In certain embodiments, at most 20.0 mmol, at most 18.0 mmol, at most 16.0 mmol, at most 14.0 mmol, or at most 12.0 mmol of the non-CO₂ acid gas is sequestered (e.g., from an environment, e.g., from an atmosphere, from a stream) per gram of the non-CO₂ acid gas sorbent. Combinations of the above-referenced ranges are also possible (e.g., between or equal to 0.01 mmol per gram and 20.0 mmol per gram, between or equal to 0.1 mmol per gram and 18.0 mmol per gram, between or equal to 2.0 mmol per gram and 12.0 mmol per gram). Other ranges are also possible. In some embodiments, including in some methods described herein, between or equal to 0.01 mmol and 20.0 mmol of the non-CO₂ acid gas is sequestered from the environment per gram of the non-CO₂ acid gas sorbent. According to certain embodiments, at least a portion of the non-CO₂ acid gas interacts with the non-CO₂ acid gas sorbent and is sequestered from an environment containing the non-CO₂ acid gas, such as from an atmosphere or a stream as noted elsewhere herein, over a period of at least 10 seconds, at least 20 seconds, at least 30 seconds, or at least 1 minute. According to certain embodiments, at least a portion of the non-CO₂ acid gas interacts with the non-CO₂ acid gas sorbent and is sequestered from an environment containing the non- CO₂ acid gas, such as from an atmosphere or a stream as noted elsewhere herein, over a period of 24 hours or less, 12 hours or less, 8 hours or less, 4 hours or less, 1 hour or less, 30 minutes or less, 10 minutes or less, or 2 minutes or less. Combinations of the above- referenced ranges are also possible (e.g., between or equal to 10 seconds and 24 hours, between or equal to 20 seconds and 12 hours, between or equal to 30 seconds and 8 hours, between or equal to 1 minute and 4 hours, between or equal to 1 minute and 10 minutes, between or equal to 1 minute and 2 minutes). Other ranges are also possible. In certain embodiments, at least 0.01 mmol of the non-CO₂ acid gas is sequestered (e.g., from the atmosphere, from the stream) per gram of the non-CO₂ acid gas sorbent per 24 hours. In some embodiments, at least 0.1 mmol, at least 0.5 mmol, at least 2.0 mmol, or at least 10.0 mmol of the non-CO₂ acid gas is sequestered from the stream per gram of the non- CO₂ acid gas sorbent per 24 hours. According to some embodiments, at most 20.0 mmol, at most 18.0 mmol, at most 16.0 mmol, at most 14.0 mmol, or at most 12.0 mmol of the non- CO₂ acid gas is sequestered from the stream per gram of the non-CO₂ acid gas sorbent per 24 hours. Combinations of the above-referenced ranges are also possible (e.g., between or equal to 0.01 mmol per gram and 20.0 mmol per gram, between or equal to 0.1 mmol per gram and 18.0 mmol per gram, between or equal to 2.0 mmol per gram and 12.0 mmol per gram). Other ranges are also possible. In certain embodiments, the temperature of the non-CO₂ acid gas sorbent is less than or equal to 1000 °C during at least a portion of the sequestration of the non-CO₂ acid gas. In certain embodiments, the non-CO₂ acid gas sorbent is at a temperature greater than the melting temperature of the salt during at least a portion of the sequestration of the non-CO₂ acid gas, such that the salt is in molten form. In certain embodiments, the temperature of the non-CO₂ acid gas sorbent is at most 1000 °C, at most 850 °C, at most 600 °C, at most 550 °C, or at most 520 °C during at least a portion of the sequestration of the non-CO₂ acid gas. In some embodiments, the temperature of the non-CO₂ acid gas sorbent is at least 200 °C, at least 300 °C, at least 400 °C, at least 450 °C, or at least 500°C during at least a portion of the sequestration of the non-CO₂ acid gas. Combinations of the above-referenced ranges are also possible (e.g., between or equal to 200°C and 1000°C, between or equal to 200°C and 600°C, between or equal to 400°C and 550°C). Other ranges are also possible. In certain embodiments, the temperature of the environment containing non-CO₂ acid gas is less than or equal to 1000 °C during at least a portion of the sequestration of the non- CO₂ acid gas. In certain embodiments, the temperature of the environment containing non- CO₂ acid gas is at most 1000 °C, at most 850 °C, at most 600 °C, at most 550 °C, or at most 520 °C during at least a portion of the sequestration of the non-CO₂ acid gas. In some embodiments, the temperature of the environment containing non-CO₂ acid gas is at least 200 °C, at least 300 °C, at least 400 °C, at least 450 °C, or at least 500°C during at least a portion of the sequestration of the non-CO₂ acid gas. Combinations of the above-referenced ranges are also possible (e.g., between or equal to 200°C and 1000°C, between or equal to 200°C and 600°C, between or equal to 400°C and 550°C). Other ranges are also possible. In some embodiments, a relatively large weight percentage of the non-CO₂ acid gas sorbent sequesters non-CO₂ acid gas during sequestration. For example, in some embodiments, at least 0.01 wt%, at least 10 wt%, or at least 20 wt% of the non-CO₂ acid gas sorbent sequesters non-CO₂ acid gas during sequestration. In some embodiments, at most 100%, at most 90 wt%, at most 80 wt%, or at most 50 wt% of the non-CO₂ acid gas sorbent sequesters non-CO₂ acid gas during sequestration. Combinations of the above-referenced ranges are also possible (e.g., between or equal to 0.01 wt% and 100 wt%, between or equal to 10 wt% and 90 wt%, between or equal to 10 wt% and 80 wt%, between or equal to 20 wt% and 50 wt%). Other ranges are also possible. In some embodiments, a method further comprises regenerating the non-CO₂ acid gas sorbent by removing, from the non-CO₂ acid gas sorbent, at least 50 mol% of the non-CO₂ acid gas sequestered by the non-CO₂ acid gas sorbent. In some embodiments, at least 60 mol%, at least 70 mol%, at least 80 mol%, at least 90 mol%, at least 95 mol%, at least 99 mol%, or at least 99.9 mol% of the non-CO₂ acid gas sequestered by the non-CO₂ acid gas sorbent is removed from the non-CO₂ acid gas sorbent. In some embodiments, the non-CO₂ acid gas sorbent remains in a liquid state throughout the sequestration and regeneration process. For example, in some embodiments, the salt remains in a liquid state throughout the sequestration and regeneration process. In certain embodiments, a method comprises performing at least one sequestration/regeneration cycle (e.g., at least one temperature swing cycle, at least one pressure swing cycle). Each sequestration/regeneration cycle is made up of a sequestration step (in which non-CO₂ acid gas is sequestered by the non-CO₂ acid gas sorbent) followed by a regeneration step (in which non-CO₂ acid gas is released by the non-CO₂ acid gas sorbent). According to certain embodiments, the non-CO₂ acid gas sorbent can be subject to a relatively large number of sequestration/regeneration cycles while maintaining the ability to sequester and release relatively large amounts of non-CO₂ acid gas. The non-CO₂ acid gas sorbent can be exposed to any of the environments (e.g., atmospheres, streams) described above or elsewhere herein during one or more (or all) of the sequestration steps of the one or more sequestration/regeneration cycles. One or more (or all) of the regeneration steps of the sequestration/regeneration cycles can be performed using a variety of suitable second environments (e.g., fluids, atmospheres, streams). In some embodiments, regeneration of the non-CO₂ acid gas sorbent can be performed by flowing an inert gas (e.g., argon, N₂) over the non-CO₂ acid gas sorbent. Non-limiting examples of suitable environment components that can be used during the regeneration step include a flow of 100 mol% N₂, or a flow of air. In some embodiments, the gas space in a desorber vessel (further described elsewhere herein) comprises a non-CO₂ acid gas, e.g., greater than or equal to 0.0001 volume% of the gas space in the desorber vessel is made of non-CO₂ acid gas(es). As would be understood by a person of ordinary skill in the art, the volume% of gas space made of the non-CO₂ acid gas can be determined by dividing the partial pressure of a non-CO₂ acid gas in the gas space by the total pressure of the gases in the gas space and multiplying by 100%. As used herein, the term “gas space” refers to a space or a volume occupied by gas in a vessel (e.g., an adsorber vessel, a desorber vessel). In some embodiments, the gas space in a desorber vessel is at the same pressure as the gas space in an adsorber vessel (further described elsewhere herein). In other embodiments, the gas space in a desorber vessel at a different (e.g., lower) pressure than the gas space in an adsorber vessel. In some embodiments, the gas space in a vessel, in a system configured for batch operation (further described elsewhere herein), during a regeneration step comprises non-CO₂ acid gas, e.g., greater than or equal to 0.0001 volume% of the gas space in the vessel is made of non-CO₂ acid gas(es). In some embodiments, the gas space in a vessel, in a system configured for batch operation, during a regeneration step is at the same pressure as the gas space in the vessel during a sequestration step. In other embodiments, the gas space in a vessel, in a system configured for batch operation, during a regeneration step is at a different (e.g., lower) pressure than the gas space in the vessel during a sequestration step. According to certain embodiments, a method comprises cycling the non-CO₂ acid gas sorbent at least 2 (or at least 5, at least 10, at least 50, at least 100, at least 1000, or at least 10,000) times. In some such embodiments, during each of the 2 (or during each of the 5, each of the 10, each of the 50, each of the 100, each of the 1000, and/or each of the 10,000) sequestration steps of the cycles, the amount of non-CO₂ acid gas that is sequestered by the non-CO₂ acid gas sorbent is at least 75%, at least 90%, at least 95%, at least 98%, at least 99%, or at least 99.9% of the amount of non-CO₂ acid gas that is sequestered by the non-CO₂ acid gas sorbent during an equivalent sequestration step of the 1^st cycle. In some such embodiments, during each of the 2 (or during each of the 5, each of the 10, each of the 50, each of the 100, each of the 1000, and/or each of the 10,000) regeneration steps of the cycles, the amount of non-CO₂ acid gas that is released by the non-CO₂ acid gas sorbent is at least 75%, at least 90%, at least 95%, at least 98%, at least 99%, or at least 99.9% of the amount of non-CO₂ acid gas that is released by the non-CO₂ acid gas sorbent during an equivalent regeneration step of the 1^st cycle. In some such embodiments, the amount of non-CO₂ acid gas that is released by the non-CO₂ acid gas sorbent during the regeneration step of the 1^st cycle is at least 75%, at least 90%, at least 95%, at least 98%, at least 99%, or at least 99.9% of the amount of non-CO₂ acid gas that is sequestered by the non-CO₂ acid gas sorbent during the sequestration step of the 1^st cycle. In some such embodiments, the amount of non-CO₂ acid gas that is sequestered during the sequestration step of the 1^st cycle, the 10^th cycle, and/or the 100^th cycle is at least 0.01 mmol, at least 0.1 mmol, at least 0.5 mmol, at least 2.0 mmol, or at least 10.0 mmol (and/or at most 20.0 mmol, at most 18.0 mmol, at most 16.0 mmol, at most 14.0 mmol, or at most 12.0 mmol) per gram of the non-CO₂ acid gas sorbent. In certain embodiments, the temperature of the non-CO₂ acid gas sorbent during the sequestration/regeneration cycles is at most 1000 °C, at most 850 °C, at most 600 °C, at most 550 °C, or at most 520 °C (and/or at least 200 °C, at least 300 °C, at least 400 °C, at least 450 °C, or at least 500°C). In certain embodiments, the time over which each of the sequestration steps and each of the regeneration steps occurs is 24 hours or less (or 12 hours or less, 8 hours or less, 4 hours or less, 1 hour or less, 30 minutes or less, 10 minutes or less, or 2 minutes or less, and/or at least 10 seconds, at least 20 seconds, at least 30 seconds, or at least 1 minute). In some embodiments, the steady state concentration of non-CO₂ acid gas in the environment to which the non-CO₂ acid gas sorbent is exposed during the sequestration steps of the sequestration/regeneration cycles is as little as 50 mol%, as little as 25 mol%, as little as 10 mol%, or as little as 1 mol% acid gas (e.g., with the balance of the environment being argon or remaining acid gases present after sequestration of a certain acid gas). In some embodiments, systems for sequestering non-CO₂ acid gas using a non-CO₂ acid gas sorbent comprising a salt in molten form are provided. Systems described herein may be used to carry out methods described herein using non-CO₂ acid gas sorbents described herein. In some embodiments, a system configured for sequestering non-CO₂ acid gas in a batch operation is provided. A system configured for batch operation may comprise any of a number of suitable components. In some embodiments, a system configured for batch operation comprises an inlet to a vessel, the vessel, and an outlet to the vessel. In some embodiments during a sequestration step, the inlet is configured to receive a fluid rich in non- CO₂ acid gas, which fluid can flow from the inlet to the vessel. In certain embodiments, the vessel is configured to contain a non-CO₂ acid gas sorbent described herein. In some embodiments during a regeneration step, the outlet is configured to receive fluid lean in non- CO₂ acid gas from the vessel, having a lower mole percentage of the non-CO₂ acid gas than the non-CO₂ acid gas-rich fluid, at least because some sequestration by the non-CO₂ acid gas sorbent occurred in the vessel. In some embodiments during a regeneration step, the inlet is configured to receive energy or work (e.g., from a heated and/or pressured gas), which can flow from the inlet to the vessel. In some embodiments during a regeneration step, the outlet is configured to receive non-CO₂ acid gas from the vessel, due to regeneration of the non- CO₂ acid gas sorbent in the vessel. In some embodiments, a system configured for sequestering non-CO₂ acid gas in a continuous operation is provided. A system configured for continuous operation may comprise any of a number of suitable components. In some embodiments, a system configured for continuous operation comprises an inlet to an adsorber vessel, the adsorber vessel, and an outlet to the adsorber vessel. In some embodiments, a system configured for continuous operation further comprises an inlet to a desorber vessel, the desorber vessel, and an outlet to the desorber vessel. In some embodiments, a system for continuous operation further comprises a first conduit between the adsorber vessel and the desorber vessel configured to transport a non-CO₂ acid gas sorbent loaded with non-CO₂ acid gas from the adsorber vessel to the desorber vessel. In some embodiments, a system further comprises a first pump configured in line with the first conduit to transport the loaded non-CO₂ acid gas sorbent. In certain embodiments, the first pump is a slurry pump. In some embodiments, a system for continuous operation further comprises a second conduit between the adsorber vessel and the desorber vessel configured to transport unloaded non-CO₂ acid gas sorbent from the desorber vessel to the adsorber vessel. In some embodiments, a system further comprises a second pump configured in line with the second conduit to transport the unloaded non-CO₂ acid gas sorbent. In some embodiments, a system further comprises a heat exchanger in line with the first conduit and/or second conduit (e.g., configured for a temperature swing operation). In some embodiments, a system further comprises a re-boiler or heater fluidically connected with the desorber vessel and the pump (e.g., configured for temperature swing operation). In some embodiments, a system further comprises a compressor fluidically connected with the desorber vessel configured to output a pure acid gas stream. Systems provided herein may comprise any suitable combination of components. Systems that are a hybrid of a system configured for batch operation and a system configured for continuous operation are also contemplated. As used herein, “loaded” non-CO₂ acid gas sorbent refers to non-CO₂ acid gas sorbent at least a portion of which (e.g., between or equal to 1 wt% and 90 wt%) has sequestered non- CO₂ acid gas. As used herein, “unloaded” non-CO₂ acid gas sorbent refers to non-CO₂ acid gas sorbent at least a portion of which (e.g., between or equal to 75 wt% and 100 wt%, between or equal to 85 wt% and 100 wt%, between or equal to 95 wt% and 100 wt%) has had a non- CO₂ acid gas removed. In some embodiments, a system (e.g., a system for batch operation, a system for continuous operation) provided herein includes at least one temperature controller configured to control the temperature of a vessel (e.g., an adsorber vessel, a desorber vessel). For example, a temperature controller may be used to set the temperature of the vessel at or above the melting temperature of the salt of the non-CO₂ acid gas sorbent, in order to maintain at least some of the salt in molten form during sequestration. Systems (e.g., a system for batch operation, a system for continuous operation) described herein can be used for a pressure swing non-CO₂ acid gas separation operation at a high temperature (e.g., between or equal to 200°C and 1000°C, between or equal to 500°C and 700°C) using a non-CO₂ acid gas sorbent described herein. For example, in some embodiments, during a sequestration step (e.g., in an adsorber vessel), the partial pressure of non-CO₂ acid gas in a first environment to which the non-CO₂ acid gas sorbent is exposed is between or equal to 0.000001 bar and 20 bar (e.g., between or equal to 0.1 bar and 10 bar), and the total pressure of the first environment to which the non-CO₂ acid gas sorbent is exposed is between or equal to 1 bar and 30 bar, or between or equal to 1 bar and 50 bar. In some embodiments, the total pressure of the first environment to which the non-CO₂ acid gas sorbent is exposed may be at least 1 bar, at least 2 bar, at least 5 bar, at least 10 bar, at least 20 bar, at least 50 bar, at least 100 bar, or more. In certain embodiments, during a sequestration step, the non-CO₂ acid gas is between or equal to 1 ppm and 30 mol% of the first environment (e.g., a stream). In some embodiments, during a regeneration step (e.g., in a desorber vessel), the partial pressure of non-CO₂ acid gas in a second environment to which the non-CO₂ acid gas sorbent is exposed is between or equal to 0 bar and 0.2 bar, and the total pressure of the second environment to which the non-CO₂ acid gas sorbent is exposed is between or equal to 1 bar and 20 bar. In some embodiments, the total pressure of the second environment to which the non-CO₂ acid gas sorbent is exposed may be less than 20 bar, less than 10 bar, less than 5 bar, less than 2 bar, less than 1.5 bar, less than 1.2 bar, less than 1.1 bar, less than 1 bar, (e.g., under vacuum), less than 0.5 bar, less than 0.1 bar, or less than 0.01 bar. In some embodiments, the difference between the total pressure of the first environment and the total pressure of the second environment is between or equal to 0 bar and 20 bar. In certain embodiments, the difference between the total pressure of the first environment and the total pressure of the second environment is at least 0.1 bar, at least 1 bar, at least 5 bar, at least 10 bar, at least 50 bar, at least 100 bar, or more. In some embodiments, the difference between the partial pressure of non-CO₂ acid gas in the first environment and the partial pressure of non-CO₂ acid gas in the second environment is between or equal to 1 bar and 20 bar. Other ranges are also possible. For example, in a pressure swing operation, a non-CO₂ acid gas sorbent may be exposed to a first environment at pressure 30 bar with a partial pressure of non-CO₂ acid gas of 1 bar during a sequestration step, and the non-CO₂ acid gas sorbent may be exposed to a second environment at a pressure of 20 bar with a partial pressure of non-CO₂ acid gas of 0 bar during a regeneration step. Systems (e.g., a system for batch operation, a system for continuous operation) described herein can be used for a temperature swing non-CO₂ acid gas separation operation at a high base temperature (e.g., between or equal to 200°C and 900°C). For example, in some embodiments, during a sequestration step (e.g., in an adsorber vessel), a first temperature of a non-CO₂ acid gas sorbent is held at between or equal to 200°C and 900°C. In some embodiments, during a regeneration step (e.g., in a desorber vessel), a second temperature of a non-CO₂ acid gas sorbent is held at between or equal to 250°C and 950°C. In some embodiments, the difference between the second temperature and the first temperature is between or equal to 10°C and 500°C (e.g., between or equal to 20°C and 400°C, 200°C). For example, in a temperature swing operation, a non-CO₂ acid gas sorbent may be held at 500°C during a sequestration step and 700°C during a regeneration step. In certain embodiments, at least a portion of the non-CO₂ acid gas sorbent containing at least the portion of the non-CO₂ acid gas is removed from the environment. For example, in some embodiments (e.g., in some embodiments where the non-CO₂ acid gas sorbent is not upconcentrated or regenerated), after the non-CO₂ acid gas sorbent has captured non-CO₂ acid gas, the non-CO₂ acid gas sorbent with captured acid gas may be discarded. In some embodiments, after the non-CO₂ acid gas sorbent has captured non-CO₂ acid gas, a solution can be added to the environment to precipitate at least a portion of the non- CO₂ acid gas sorbent. In some such embodiments, the solution contains calcium ions. In certain embodiments, adding the solution results in the precipitation of CaSO₄. As one example, in some embodiments, limewater can be added to recover aqueous non-CO₂ acid gas sorbent and gypsum. U.S. Provisional Patent Application No.62/971,488, filed February 7, 2020, and entitled “Treatment of Acid Gases Using Molten Alkali Metal Borates, and Associated Methods of Separation,” is incorporated herein by reference in its entirety for all purposes. Processes for Regenerating Sorbents and Associated Systems Also disclosed herein are processes for regenerating sorbents and associated systems. Certain embodiments are related to the use of steam to remove one or more captured acid gases from the sorbent. The sorbent can comprise, in some embodiments, a molten material, such as a molten alkali borate material. The use of steam as a sorbent regenerant, especially at high temperatures, can provide a variety of advantages. For example, in some cases, after the steam has been used to remove one or more acid gases from the sorbent, the steam (along with removed acid gases) can be cooled such that the steam condenses while the acid gas remains in gaseous form. This can allow for relatively easy separation of the steam and the acid gas. Moreover, steam is commonly produced in many industrial processes that generate acid gases, making the source of the regenerant (e.g., steam) readily available. The use of steam as a regenerant can be particularly useful, in some cases, in systems in which the acid gas sorbent is at high temperatures. For example, in certain embodiments, steam is used to regenerate molten sorbents, such as molten alkali metal borate material. Steam can generally remain chemically stable at such high temperatures, and, as noted above, the steam condensation cycle can allow for relatively facile separation of the acid gas released during regeneration and the steam used during regeneration. Certain embodiments are related to regenerating a sorbent. In some embodiments, regenerating the sorbent comprises exposing the sorbent to an environment containing steam. FIG.9A is a schematic diagram illustrating one such process. In FIG.9A, sorbent 902 is exposed to steam within head space 904. “Steam,” as used herein, refers to water (H₂O) in its gaseous form (also referred to as its vapor form). Both subcritical steam and supercritical steam are considered to fall within the scope of the term “steam” as these terms are used herein. In some embodiments, exposure of the sorbent to the steam results in at least part of an acid gas associated with the sorbent to be separated from the sorbent. For example, referring back to FIG.9A, in some embodiments, steam within vessel 906 (e.g., within head space 904 and/or flowed through sorbent 902) can interact (e.g., physically interact) with sorbent 902 such that at least a part of an acid gas associated with sorbent 902 is removed from sorbent 902. In some embodiments, exposure of the sorbent, by which an acid gas has been captured, to steam may reduce the partial pressure of the acid gas in an environment around the sorbent. This reduction of partial pressure of the acid gas by the steam may facilitate the release of acid gas from the sorbent (e.g., via a change in the capture equilibrium, such as a change in an adsorption equilibrium, an absorption equilibrium, a chemical reaction equilibrium, and/or a diffusion equilibrium). While FIG.9A shows steam interacting with the sorbent, it should be understood that in some embodiments, the steam does not interact with sorbent. That is to say, in some embodiments, the sorbent does not interact (e.g., physically interact, chemically interact) with the sorbent. In some embodiments, the steam is chemically inert with the sorbent. In some embodiments, the steam may occupy a volume (e.g., a head space) proximate a sorbent during sorbent regeneration. In some embodiments, for at least a portion of the time during which the regeneration is performed, the head space contains steam in an amount of at least 75 wt%, at least 85 wt%, at least 95 wt%, at least 99 wt%, at least 99.9 wt%, or more. In some embodiments, the amount of steam within the headspace does not fall below 50 wt%, 25 wt%, 10 wt%, or 1% during the regeneration step. The remaining portion of the head space that is not occupied by the steam can be, in some embodiments, acid gas. In some embodiments, the molar ratio of steam to acid gas in the sorbent (i.e., the ratio between the moles of steam in the gas phase and the moles of acid gas held in the sorbent phase) during sorbent regeneration may have a particular value. In some embodiments, for at least a portion of the time during which the regeneration is performed, the molar ratio of steam in the gas phase to acid gas in the sorbent is at least 1, at least 10, at least 100, at least 1000, at least 10,000, or more. In some embodiments, the molar ratio of steam to acid gas in the sorbent does not fall below 0.5, below 0.1, below 0.01, or below 0.001 during the regeneration step. This molar ratio may exist within any portion of the release environment, for example, within a sorbent contained within the release environment. In some embodiments, the molar ratio of steam to sorbent is 0.1, 1, 10, 100, 1000, or in a range between these values. In some embodiments, an inlet stream to a vessel containing the sorbent that is being regenerated can contain steam in an amount of at least 75 mol%, at least 85 mol%, at least 95 mol%, at least 99 mol%, at least 99.9 mol%, or more. In some embodiments, an outlet stream from a vessel containing the sorbent that is being regenerated can contain steam in an amount of at least 50 mol%, at least 75 mol%, at least 90 mol%, or more. In certain embodiments, at least 75 mol%, at least 90 mol%, at least 95 mol%, at least 99 mol%, or at least 99.9 mol% of an outlet stream from a vessel containing the sorbent that is being regenerated is made up of steam and/or acid gas. In some embodiments, the steam and the sorbent can be separated from each other, and at least part of the acid gas that was removed from the sorbent accompanies the steam, thus separating the acid gas from the sorbent. For example, referring to FIG.9A, in some embodiments, the steam may be removed from vessel 906 via outlet 920. At least part of the acid gas that was removed from sorbent 902 can accompany the steam that is removed via outlet 920, thus separating this portion of the acid gas from sorbent 902. The steam and/or sorbent can be introduced to each other in any of a variety of suitable ways. In some embodiments, the steam can be flowed into a vessel containing the sorbent. As one example, the steam can be used as (or as part of) a sweep stream that is flowed across the sorbent. For example, in FIG.9A, steam can be transported into vessel 906 via inlet stream 908. In some embodiments, the sorbent may be flowable and may be transported through a vessel containing the steam. Other methods are also possible. In some embodiments, the acid gas that is released from the sorbent can have originated from exposure of the sorbent to the acid gas. One exemplary process is described in more detail below in association with FIG.10. Examples of acid gases that can be captured by the sorbent and subsequently released are described in more detail below. As used herein, the term “regenerating” refers to the removal of acid gas from the sorbent such that the capacity of the sorbent to capture acid gas is increased. In some embodiments, removal of an acid gas from the sorbent allows additional acid gas to be captured by the sorbent so that the sorbent may be recycled. That is to say, regenerating may comprise removal of an initial amount of acid gas such that the capacity of the sorbent to capture a subsequent amount of acid gas is increased. In some embodiments, regeneration may take place in a regenerator (e.g., a vessel, such as a desorber). In some embodiments, sorbent regeneration may occur at least one time, at least 10 times, at least 10³ times, at least 10⁴ times, at least 10⁶ times or more. It should be understood that regeneration includes both partial regeneration of the sorbent’s ability to capture acid gas as well as complete regeneration of the sorbent’s ability to capture acid gas. In some embodiments, at least 1 wt% (or at least 5 wt%, at least 10 wt%, at least 25 wt%, at least 50 wt%, at least 75 wt%, at least 90 wt%, at least 95 wt%, at least 99 wt%, at least 99.9 wt%, or more) of the sorbent is regenerated during the regeneration step. In certain embodiments, at least 1 wt% (or at least 5 wt%, at least 10 wt%, at least 25 wt%, at least 50 wt%, at least 75 wt%, at least 90 wt%, at least 95 wt%, at least 99 wt%, at least 99.9 wt%, or more) of the sorbent that has captured acid gas may be regenerated during the regeneration step. Sorbent regeneration may also be described in terms of an amount of captured acid gas released from the sorbent during regeneration. In some embodiments, a mole percentage of acid gas released from the sorbent during regeneration is at least 1 mol% (or at least 5 mol%, at least 10 mol%, at least 25 mol%, at least 50 mol%, at least 75 mol%, at least 90 mol%, at least 95 mol%, at least 99 mol%, at least 99.9 mol%, or more). In certain embodiments, at least 1 mol% (or at least 5 mol%, at least 10 mol%, at least 25 mol%, at least 50 mol%, at least 75 mol%, at least 90 mol%, at least 95 mol%, at least 99 mol%, at least 99.9 mol%, or more) of the acid gas captured by the sorbent may be regenerated during the regeneration step. Any of a variety of suitable sorbents can be used in various of the embodiments disclosed herein. As used herein, the phrase “sorbent” is used to describe a material that is capable of removing acid gas (e.g., any of the acid gases described elsewhere herein) from an environment containing the acid gas. In some embodiments, the sorbent may function as a sequestration material. That is to say, the sorbent may be capable of sequestering acid gas. In some embodiments, the sorbent may function as an absorption material. That is to say, the sorbent may be capable of absorbing acid gas. In some embodiments, the sorbent may function as an adsorption material. That is to say, the sorbent may be capable of adsorbing acid gas. In some embodiments, the sorbent may chemically react with the acid gas. In some embodiments, the acid gas may diffuse into the sorbent. Combinations of these mechanisms are also possible. For example, in some embodiments, the sorbent may capture the acid gas(es) via chemisorption. Other capture mechanisms may exist. Regeneration of the sorbent can involve a process that is the reverse of the process used to capture the acid gas. For example, if the sorbent captures the acid gas(es) via a chemical reaction, regeneration of the sorbent can involve, in certain cases, allowing the reverse of the chemical reaction used to capture the acid gas(es) to proceed. As another example, if the sorbent captures the acid gas(es) via adsorption, regeneration of the sorbent can involve breaking the adsorptive bonds between the sorbent and the captured acid gas(es). In some embodiments, the sorbent may comprise an alkali metal borate, which can be used as sorbents to remove acid gas from streams (e.g., an input stream, an output stream). Specific examples of materials that can be used as sorbents are provided in more detail below. The sorbent may be, in some embodiments, flowable. For example, in some embodiments, the sorbent may be in molten form. Those of ordinary skill in the art would understand that a molten material (e.g., a molten salt) is different from a solubilized material (e.g., a salt that has been dissolved within a solvent). As one example, in some embodiments, the sorbent comprises a molten alkali metal borate. Molten alkali metal borates, in some embodiments, hold promise to improve the approach taken to carbon capture by allowing for liquid-based process designs at the high temperatures involved in most CO₂ emissions. At high temperatures the high-quality thermal energy content of all streams involved in a capture system may be recovered effectively. Fluid sorbents (e.g., molten alkali metal borates) further allow for simple, efficient liquid- liquid heat exchangers and generally provide an added benefit in their easy transfer between vessels dedicated to capture and release via transfer pumps. In certain cases, the molten alkali metal borate’s high working capacity, ultra-fast kinetics, and intrinsic regenerability can impart them with exceptional potential. The use of certain sorbents (e.g., sorbents comprising a salt in molten form, or other flowable sorbents) may provide the ability to use the sorbent at an elevated temperature, that is, at a temperature greater than or equal to the melting temperature of the sorbent (e.g., greater than or equal to 200 ºC). The use of sorbents capable of operating at high temperatures can be particularly useful when steam is used to remove acid gas (e.g., by using the steam as a sweep gas), as it can allow for relatively easy subsequent separation of the acid gas and the steam (e.g., via condensation of the steam). The temperature may be higher than the melting temperature of the sorbent as well. In some embodiments, the temperature of a sorbent (e.g., a salt in molten form) may be at least 250 °C, at least 300 °C, at least 350 °C, at least 400 °C, at least 450 °C, or at least 500 ºC, or higher. In some embodiments in which the sorbent is used at an elevated temperature, any of a variety of suitable amounts of the sorbent (e.g., greater than or equal to 1 wt%, greater than or equal to 10 wt%, greater than or equal to 50 wt%, greater than or equal to 75 wt%, greater than or equal to 90 wt%, greater than or equal to 99 wt%, or all of the sorbent) will be at that elevated temperature (e.g., greater than or equal to 200°C, greater than or equal to 250°C, greater than or equal to 300°C, greater than or equal to 350°C, greater than or equal to 400°C, greater than or equal to 450°C, greater than or equal to 500 ºC, and/or within any of the other temperature ranges mentioned above or elsewhere herein). In certain embodiments, the process can optionally take place in a pressure swing operation. The temperature of operation may refer to the temperature of the sorbent itself, which can be essentially equal to or different from the temperature of the environment to which the sorbent is exposed. In some embodiments, the environment in which the sorbent was exposed to the acid gas is at the same, or similar, temperature as the environment in which the sorbent was regenerated. As noted above, regeneration of the sorbent can involve removing acid gas (e.g., a single acid gas, more than one acid gas) from the sorbent. Non-limiting examples of acid gases include carbon dioxide (CO₂), sulfur monoxide (SO), sulfur dioxide (SO₂), nitrogen dioxide (NO₂), hydrogen sulfide (H₂S), sulfur trioxide (SO₃), nitric oxide (NO), nitrous oxide (N₂O), dinitrogen trioxide (N₂O₃), dinitrogen tetroxide (N₂O₄), dinitrogen pentoxide (N₂O₅), and/or carbonyl sulfide (COS). In some embodiments, the acid gas comprises at least a nitrogen oxide and CO₂. In some embodiments, the acid gas comprises at least CO₂. Regeneration of the sorbent from other acid gases is also possible. In some embodiments, regeneration of a sorbent comprises removing a single acid gas that is present in (e.g., captured within) the sorbent. In other embodiments, the sorbent may capture multiple acid gases (e.g., CO₂ and SO₂; SO₂ and NO₂; CO₂; SO₂; and CO₂; etc.). Wherever an “acid gas” is described herein, it should be understood that, unless explicitly stated to the contrary, a single acid gas may be present or multiple acid gases may be present. In some embodiments, the environment within which the steam is exposed to the sorbent can be at a relatively high temperature (e.g., superheated). The use of relatively high temperatures can ensure that the steam does not condense during exposure of the sorbent to the steam during sorbent regeneration. This can ensure that the steam and the acid gas may be transported away from the sorbent relatively easily, while also preserving the ability to separate the steam from the acid gas at a downstream location. In some embodiments, the environment within which the steam is exposed to the sorbent can be at a temperature of at least 200 °C, at least 250 °C, at least 300 °C, at least 350 °C, at least 400 °C, at least 450 °C, at least 500 °C. Other temperatures are possible. In some embodiments, the temperature of the steam during the exposure of the sorbent to the steam can be at least 200 °C, at least 250 °C, at least 300 °C, at least 350 °C, at least 400 °C, at least 450 °C, or at least 500 °C. Other temperatures are also possible. The pressure of the regeneration environment may be within any of a variety of suitable pressures. In some embodiments, the pressure of the regeneration environment may be at least 0.01 bar, at least 0.1 bar, at least 1 bar, or at least 10 bar. In some embodiments, it can be advantageous to employ no or relatively low vacuum within the regeneration environment (e.g., pressures of at least 0.9 bar or higher). Employing no or relatively low vacuum may reduce complexity and reduce energy consumption associated with generating and/or maintaining the vacuum. In some embodiments, it can be advantageous to operate at high pressures (e.g., pressures above 1.1 bar, 5 bar, 10 bar, or 20 bar). Operating at high pressures may improve heat recovery and may also increase the electrical output of a steam turbine. In some embodiments, the pressure in the regeneration environment is 1 bar, 3 bar, 5 bar, 10 bar, 20 bar, 30 bar, 50 bar, or in a range between these pressures. In some embodiments, the partial pressure of gas (e.g., steam, an acid gas) within the regeneration environment may be a variety of suitable pressures. In some embodiments, the partial pressure of a gas within the regeneration environment is at least 0.000001 bar, at least 0.0001 bar, at least 0.01 bar, or at least 1 bar. Providing a particular partial pressure of a gas can provide an adequate driving force for the release of an acid gas from a sorbent. The amounts of steam and acid gas containing sorbent within the regeneration environment may establish any of a variety of suitable molar ratios. In certain embodiments, the molar ratio of steam to acid gas in the sorbent is at least 1, at least 10, at least 1000, or at least 10,000. The use of relatively high ratios of steam to acid gas in the sorbent can allow one to remove a relatively large amount of acid gas from the sorbent relatively efficiently. For example, consider a situation in which one contacts a stream containing 15 moles of CO₂ and 85 moles of N₂ with a sorbent, and the 15 moles of CO₂ are captured by the sorbent. Generally, when regenerating the sorbent, the partial pressure of acid gas within the regeneration stream would need to be reduced to at least below the partial pressure of acid gas that was present in the original CO₂/N₂ stream to which the sorbent was exposed. In this case, a supply of at least 85 moles of steam would be needed, and the ratio of steam to acid gas in the sorbent would need to be at least 85/15 = 5.7. Supplying even more steam would help to even further drive sorbent regeneration. Some embodiments may further comprise exposing the sorbent to an acid gas such that the acid gas is captured by the sorbent. In some embodiments, this may occur before the sorbent has been at least partially regenerated. Referring now to FIG.9B, system 900 may comprise inlet stream 910, in addition to second inlet stream 908. Inlet stream 910 may allow for the addition of an acid gas to sorbent 902, such that the acid gas is captured by sorbent 902. As one example, an exhaust stream from an industrial process may be transported through inlet 910, after which the exhaust stream is exposed to sorbent 902. In some such embodiments, sorbent 902 may capture one or more acid gases from the exhaust stream of the industrial process, producing a relatively clean stream (e.g., a stream reduced in an amount of one or more acid gases relative to the amount of one or more acid gases present in exhaust stream from the industrial process) that can exit vessel 906 via outlet 920. In some such embodiments, it may be desirable to regenerate sorbent 902. The regeneration can be accomplished, for example, by transporting steam into vessel 906 (e.g., via inlet 908) such that spent sorbent 902 is exposed to the steam. In some such embodiments, exposure of sorbent 902 to the steam results in acid gas being removed from sorbent 902, thus regenerating sorbent 902. Optionally, sorbent 902 can then be reused in a subsequent acid gas capture step (e.g., by contacting sorbent 902 with an exhaust stream containing one or more acid gases for a second time). In certain embodiments in which the sorbent is exposed to and captures acid gas, the temperature of the environment in which the sorbent was exposed to the acid gas may be the same, or similar to, the temperature of the environment in which the sorbent is regenerated. In certain embodiments, the temperature of the environment in which the sorbent is exposed to and captures the acid gas is within 200°C (or within 100 °C, within 50°C, within 10°C, or within 1°C) of the temperature of the environment in which the sorbent is regenerated. In some embodiments, the temperature of the environment in which the sorbent is exposed to and captures the acid gas is greater than or equal to 200 °C, greater than or equal to 250 °C, greater than or equal to 300 °C, greater than or equal to 350 °C, greater than or equal to 400 °C, greater than or equal to 450 °C, greater than or equal to 500 °C, greater than or equal to 600 °C, greater than or equal to 700 °C, greater than or equal to 800 ºC, or higher, and/or less than or equal to 1000 °C. In some embodiments, the environment is at a temperature of 800°C, 700°C, 600°C, 500°C, or above 200°C, or in a range between these temperatures. Combinations of the above-referenced ranges are also possible (e.g., greater than or equal to 200 °C and at most 700 °C). Other ranges are possible. In some embodiments, the steam that is used to regenerate the sorbent may be subject to downstream processing after the sorbent regeneration. For example, in some embodiments, after the steam is used to regenerate the sorbent, the method further comprises cooling the mixture of steam and acid gas such that the condensed steam is separated from the acid gas. As noted above, the ability to condense steam while maintaining the acid gas in gaseous form can allow for relatively easy separation of the steam from the acid gas, providing a relatively pure stream of acid gas and a relatively pure stream of water. In some embodiments, the condensed steam may be recycled and converted back to steam to be reused in sorbent regeneration. In some embodiments, the acid gas may be recovered in a relatively pure form (e.g., in a relatively pure acid gas stream) once the steam has been condensed from the acid gas and stream mixture. In some embodiments, the acid gas is recovered at a purity of greater than 50 wt%, greater than 60 wt%, greater than 70 wt%, greater than 80 wt%, greater than 90 wt%, greater than 95 wt%, greater than 99 wt%, or greater than 99.99 wt%. In some embodiments, the acid gas is recovered at a purity of 100 wt%. In some embodiments, the acid gas is recovered and subsequently compressed to ensure a purity of greater than 50 wt%, greater than 60 wt%, greater than 70 wt%, greater than 80 wt%, greater than 90 wt%, greater than 95 wt%, greater than 99 wt%, or greater than 99.99 wt%. In some embodiments, a mixture of acid gas and steam is cooled in a heat exchanger to generate useful energy. The cooling of the mixture in a heat exchanger may increase the efficiency of energy use in an overall system for regenerating a sorbent. In certain embodiments, the mixture of acid gas and steam is cooled in a heat exchanger prior to separation in the condenser to generate useful energy. As one example, a turbine can be used to generate electrical energy as the steam is cooled. In some embodiments, the condensed steam is heated and recycled back into the regeneration environment. In this way, the condensed steam may be recycled for further use. In some embodiments, sorbent regeneration may occur in multiple cycles. In some such embodiments, steam used during one sorbent regeneration step may be condensed from a mixture of steam and acid gas, re-heated in a subsequent step, and used again during the next sorbent regeneration step. In certain embodiments, the steam can be reused at least once, at least twice, at least 10 times, at least 100 times, at least 1000 times, or more. Steam quality may be maintained in a variety of ways. In general, “steam quality” refers to the proportion of saturated steam (vapor) in a stream relative to the amount of condensate (liquid) in the stream. A steam quality of 100 indicates that the stream is 100% steam, and a steam quality of 0 indicates that the steam is 100% liquid. As used herein, steam quality is said to be “maintained” when at least some energy is input into the steam stream and/or the steam stream condensate. The energy that is input into a steam stream can be used, for example, to maintain or increase the temperature of the steam. The energy that is input into the steam stream condensate can be used, for example, to convert condensed steam (water) back into steam. The quality of steam can be maintained via any of a number of sources relative to the sorbent regeneration process (e.g., an energy source internal to the process, or an energy source external to the process). In certain embodiments, the quality of steam is maintained, at least in part, by an energy source internal to the process that generates the acid gas. One example of such an embodiment is shown in FIG.11A. In FIG.11A, acid gas source 1110 comprises energy source 1115 internal to the process that generates the acid gas. Energy 1125 from energy source 1115 maintains the quality of the steam within steam source 1120. Acid gas from acid gas source 1110 may enter regenerator 1140 via acid gas inlet 1130 while steam, maintained, at least in part, by the energy source 1115 internal to acid gas source 1110, may enter regenerator 1140 via steam inlet 1135. In some such embodiments, the energy source can originate from fuel within the process that generates the acid gas. In such cases, the steam quality can be maintained, at least in part, by the energy content of fuel within the process that generates the acid gas. For example, in FIG.11A, in some embodiments, energy source 1115 can be fuel from within acid gas source 1110. One such embodiment is shown in FIG. 16 and described in more detail below in Example 3. In some embodiments, the steam quality is maintained, at least in part, by an energy source external to the process that generates the acid gas. One example of such an embodiment is shown in FIG.11B. In FIG.11B, the process that generates the acid gas is acid gas source 1110; however, now energy source 1115, external to acid gas source 1110, maintains the steam quality of steam source 1120 via energy exchange 1125. Acid gas from acid gas source 1110 may enter regenerator 1140 via acid gas inlet 1130 while steam, maintained, at least in part, by the energy source 1115 external to acid gas source 1110, may enter regenerator 1140 via steam inlet 1135. In some embodiments, the steam quality is maintained, at least in part, by a steam cycle powered by a process separate from the process that generates the acid gas. For example, in FIG.11B, in some embodiments, energy source 1115 can be an external steam cycle-powered process. One such embodiment is shown in FIG.15B and described in more detail below in Example 3. In some embodiments, the environment within which the regeneration takes place is part of an industrial process. “Industrial processes” are those that involve chemical, physical, electrical, or mechanical steps to aid in the manufacturing of an item or items and/or in the generation of power. In some embodiments, the environment may be part of an industrial process comprising the combustion of fuels, including natural gas, oil, coal, biomass, or the production of chemicals including, steel, cement, or hydrogen. Others may exist. Additional non-limiting examples of industrial processes include power production process (e.g., within a power plant), chemical manufacturing processes, and machine manufacturing processes. In some embodiments, the industrial process comprises a natural gas combined cycle (NGCC) and/or steam methane reforming (SMR) process, optionally with sorption enhanced reforming (SER). In certain embodiments, the industrial process comprises NGCC with carbon capture. In some embodiments, the industrial process comprises cement production with carbon capture. In some embodiments, steam is taken directly from the steam cycle of a power plant which is producing the acid gas that is captured by the sorbent (e.g., coal power plant which may itself produce substantial amounts of steam). In some embodiments, steam is generated in a separate steam cycle using the energy produced by the power plant (e.g., natural gas power plant which may not produce much steam itself). In another embodiment, steam is taken directly from the steam cycle of a power plant that is not producing the acid gas being captured (e.g., steam generated by a concentrated solar plant to regenerate CO₂ captured in a cement plant). In yet another embodiment, steam may be generated in a separate steam cycle using energy produced externally (e.g., electrical energy from a wind turbine used to reheat steam to regenerate CO₂ captured in a cement plant). As noted above, any of a variety of sorbents may be used in accordance with certain embodiments. According to certain embodiments, the sorbent comprises an alkali metal borate. The alkali metal borate generally includes at least one alkali metal, boron, and oxygen. As noted above, the term “alkali metal” is used herein to refer to the following six chemical elements of Group 1 of the periodic table: lithium (Li), sodium (Na), potassium (K), rubidium (Rb), cesium (Cs), and francium (Fr). In some embodiments, the at least one alkali metal of the alkali metal borate comprises cationic lithium (Li), sodium (Na), potassium (K), rubidium (Rb), and/or cesium (Cs). In some embodiments, the at least one alkali metal comprises lithium (Li), sodium (Na), and/or potassium (K). In certain embodiments, the at least one alkali metal comprises Li and Na in equal amounts. In some embodiments, the fractional stoichiometry of a sorbent (e.g., a salt, an alkali metal borate, a molten alkali metal borate) described herein can be expressed as A_xB_1-xO_1.5-x, wherein A is one or more alkali metals (e.g., Li, Na, Li, and Na), B is boron, O is oxygen, and x is between zero and 1. In certain embodiments, x may refer to a mixing ratio, as is described below. In some embodiments, the fractional stoichiometry is that of the sorbent in solid form before melting the sorbent. In some embodiments, the fractional stoichiometry is that of the sorbent after melting the sorbent. Consistent with its usage above, as used herein, the term “mixing ratio” of an alkali metal cation or combination of metal cations in a sorbent refers to the ratio of moles of metal cation(s) in a sorbent to the total of moles of metal cation(s) plus moles of boron in the sorbent. For example, the mixing ratio of sodium in Na₃BO₃ is 3/(3+1) = 0.75; the mixing ratio of alkali metals in (Li_0.5Na_0.5)₃BO₃ is (0.5*3 + 0.5*3)/(3+1) = 0.75. In some embodiments, the mixing ratio is at least 0.5, at least 0.6, or at least 0.667. In some embodiments, the mixing ratio is at most 0.9, at most 0.835, at most 0.8, at most 0.75, or at most 0.7. Combinations of the above-referenced ranges are also possible (e.g., between or equal to 0.5 and 0.9, between or equal to 0.6 and 0.8, between or equal to 0.7 and 0.8). Other ranges are also possible. Without wishing to be bound by theory, there may be a mixing ratio (for a certain alkali metal cation or combination of metal cations) below which the acid gas uptake capacity of the sorbent is less than desirable. Without wishing to be bound by any theory, there may be a mixing ratio (for a certain alkali metal cation or combination of metal cations) above which the regeneration efficiency of the sorbent is less than desirable. In some embodiments, the alkali metal comprises lithium (Li), sodium (Na), potassium (K), and/or a mixture of these. In some embodiments, the alkali metal comprises Li and Na in equal amounts. It should be understood that the embodiments disclosed herein are not limited to those in which alkali metal borates (molten or otherwise) are used as sorbents, and in other embodiments, other sorbents may be used. U.S. Provisional Patent Application No.62/988,436, filed March 12, 2020, and entitled “Processes for Regenerating Sorbents, and Associated Systems”; U.S. Provisional Patent Application No.62/979,628, filed February 21, 2020, and entitled “Processes for Regenerating Sorbents, and Associated Systems”; and U.S. Provisional Patent Application No.62/932,410, filed November 7, 2019, and entitled “Process for Regenerating Sorbents at High Temperatures,” are each incorporated herein by reference in their entirety for all purposes. The following examples are intended to illustrate certain embodiments of the present invention but do not exemplify the full scope of the invention. EXAMPLE 1 This example describes the removal of several non-CO₂ acid gases in comparison to CO₂ under both reducing and oxidizing environments. An acid gas is any gas that forms an acidic solution with water. Those most relevant to industrial emissions are various oxides of sulfur (SO_x) and nitrogen (NO_x), hydrogen sulfide (H₂S), and carbon dioxide (CO₂). Typically, acid gases are environmental pollutants, such as greenhouse gases or producers of acid rain, and are, in some cases, severely harmful to human health. Recent interest in capturing CO₂ emissions to combat global warming, masks an older effort to treat acid gas emissions more broadly, such as non-CO₂ acid gases. Many lessons can be learned from these successes, both in terms of strategies for the large- scale deployment of emission control technology, and from the specific technological challenges that were overcome. Indeed, many of today’s best options for carbon capture trace their roots to the treatment of other acid gases (e.g., non-CO₂ acid gases). For example, it was originally desirable for amines to remove H₂S, but not CO₂, in natural gas processing. The method of capture may be the same in each case, in a sorber the acid gas is contacted with a basic sorbent to form a neutral salt, which is typically destabilized in a desorber by a change in conditions, for example temperature, with the recovered gas sent for further treatment, storage, or utilization. The basicity of the various sorbents has been tuned over decades to target specific acid gases and lately, among other process challenges, to minimize the energy penalty of the release step. Real systems present both a challenge and an opportunity in that they contain multiple acid gases at varying concentrations. The opportunity is to treat multiple acid gases simultaneously thereby reducing equipment costs and system complexity. The challenge is to manage the products and maintain ever stricter limits on acid gas emissions. A recent example of this trend can be seen in the shipping industry, where SO_x emissions are being more tightly controlled from 2020 and the industry aims to cut 70% of CO₂ emissions by 2050. In understanding the relevance of the various acid gases to specific industrial processes, it is convenient to distinguish between an oxidizing atmosphere, where an excess of oxidizing agent exists, and a reducing atmosphere, where no such oxidizing agent exists. If feedstock’s containing sulfur are processed under an oxidizing environment sulfur is emitted in the form of SO_x, of which SO₂ is the most pertinent. Common examples include the combustion of coal, oil, natural gas, and, biomass, production of cement, and the smelting of ores. On the other hand sulfur forms H₂S in reducing environments, such as those associated with pre-combustion technologies, hydrogen production, and gas-sweetening. Similarly, nitrogen is present in many feedstock’s giving rise to fuel NO_x, of which NO₂ and NO are the most relevant. In addition, nitrogen is present in the air making thermal NO_x emissions particularly pervasive in oxidizing environments. However, in some embodiments, under a reducing atmosphere nitrogen is usually emitted rather than NO_x. For various high temperature sources Table 1, below, presents the typical range of uncontrolled acid gas emissions. Table 1. Typical acid gas concentration by source. CO₂, SO_x, and NO_x correspond to post- combustion designs while the H₂S concentration corresponds to pre-combustion.

High temperature capture, typically around 600 °C or 700 °C, may offer many advantages over lower temperature operation including greater opportunities for efficient heat recovery, so-called “sorption enhanced” designs, and different chemistries with faster kinetics and higher capacities. The recent discovery of molten alkali metal borates (A_xB_1-xO_1.5-x) as high temperature liquid phase sorbents for carbon capture, in some embodiments, represents a significant advance in realizing efficient low-cost carbon capture facilities. Without wishing to be bound by any theory, two distinct reaction mechanisms have been identified, one where the molten liquid reacts to form solid crystalline products and another where the molten liquid reacts to form molten liquid products. In some embodiments, the alkali metal borates with compositions, Na_xB_1-xO_1.5-x (x = 0.75) and (Li_0.5Na_0.5)_xB_1-xO_1.5-x (x = 0.75) are the representative examples of “liquid-to-solid” and ‘liquid-to-liquid’ type non-CO₂ acid gas sorbents, respectively. As described herein, the interaction between other acid gases (e.g., non-CO₂ acid gases) and this new class of high-temperature non-CO₂ acid gas sorbents are discussed with a focus on the opportunity-challenge presented by real systems. In some embodiments, the performance of molten alkali metal borates at the concentrations and mixtures applicable to real systems using SO₂ as a representative example are described, then the reaction mechanism for the industrially significant gases are described, and finally the implications on the design of high-temperature capture facilities with a comparison between the state-of-the- art in carbon capture and the molten alkali metal borates are described further below. Experimental & Methodology Sample Preparation Lithium hydroxide (LiOH, 98%), sodium hydroxide (NaOH, 97%), and boric acid (H₃BO₃, 99.5%) were purchased from Sigma-Aldrich. The alkali metal borate samples, A_xB_1- xO1.5-x, where A is an alkali metal and x is the mixing ratio, were prepared from mixed precipitants of alkali metal hydroxide and boric acid. The mixtures were weighed and dissolved in 0.1 g/mL Milli-Q (Millipore) deionised water. The water was evaporated at 120 °C for several hours followed by 2 hours at 400 °C to release residual moisture and CO₂; a final pretreatment step at 800 ºC was conducted for 60 minutes in-situ to obtain the targeted composition. Performance Analysis Mixtures of 1 mol% acid gas, balance nitrogen (N₂), were obtained (Airgas) for carbon dioxide (CO₂), sulfur dioxide (SO₂), hydrogen sulfide (H₂S), and nitrogen dioxide (NO₂).20% CO₂ was mixed with 1 mol% acid gas to obtain various mixtures of 10 mol% CO₂ & 0.5 mol% acid gas. The performance of the non-CO₂ acid gas sorbents was analyzed by the weight variation of the sample inside a thermogravimetric analyzer (TGA, Q50 TA Instruments) on exposure to a flow of gas. In each case, the sample mass was ~5 mg and sample gas flow rate ~30 mL/min. The final pretreatment step was carried out inside the TGA under 200 mL/min N₂. The weight change on exposure to acid gas was normalized by the sample mass after final pretreatment to obtain the loading in mg of gas per gram of non-CO₂ acid gas sorbent, in some cases for better comparison the weight change was converted into mmol of acid gas using the molecular weight of the gas. Temperature ramps were carried out after final pre- treatment from 200 °C to 800 °C at 5°C/min. Materials Characterization The phase composition and crystallographic features were examined by powder X-ray diffractometry (XRD) and high temperature powder X-ray diffractometry (HTXRD) (XRD: PANalytical X’Pert Pro Multipurpose Diffractometer with Cu-k_α X-ray (λ=1.541 Å)), in which the samples were placed on a Pt-sheet substrate. The peaks in the XRD spectra were identified by referring to the ICDD PDF-4+2016RDB database. Samples were prepared ex- situ in a tube furnace (GSL-1800, MTI Corp), under a continuous flow of 1 mol% acid gas balance N₂ for 60 minutes. Results and Discussion From Table 1, above, some of the industrially relevant acid gas concentrations can vary by orders of magnitude. In this example, SO₂ is selected as a representative species at the higher end of concentrations (1 mol%, 0.5 mol%, and 0.1 mol%) where the acid gases influence would be most significant, and comparisons are drawn to CO₂ capture at the same concentration. At 600 °C, the performance of the sodium borate Na_xB_1-xO_1.5-x (x = 0.75) for SO₂ capture was similar to CO₂ capture on a molar basis (FIG.3A). For an acid gas concentration of 1 mol% and 0.5 mol% the capacity was consistently ~6 mmol/g but, 0.1 mol% was too low for the reaction to reach completion in 60 minutes. However, there was a clear interaction between the acid gases and the non-CO₂ acid gas sorbent even at this low concertation. Exposure to nitrogen in the release step stimulated pressure swing operation by reducing the partial pressure of the acid gas. At 600 °C CO₂ was very slowly released whereas SO₂ was retained by the non-CO₂ acid gas sorbent with a slight increase in loading. As the acid gas concentration dropped from 0.1 mol% to 0% during exposure to nitrogen the non-CO₂ acid gas sorbent continued to remove any left-behind SO₂ still present in the head space, suggesting concentrations substantially less than 0.1 mol% could be treated effectively. At 700 °C (FIG.3B), the capacity for CO₂ was reduced at lower concentrations as CO₂ existed in the melt below supersaturation conditions, while the capacity for SO₂ was elevated. Without wishing to be bound by any theory, the elevated SO₂ loading suggested a different reaction occurred that allowed for a higher capacity at 700 °C compared to 600 °C. Release of CO₂ was more favorable at 700 °C but in each case SO₂ was retained at the capacity reached during the uptake step. This suggests that while the reaction with CO₂ is easily reversed the reaction with SO₂ is irreversible up to at least 700 °C. Likewise for the lithium-sodium borate (Li_0.5Na_0.5)_xB_1-xO_1.5-x (x = 0.75) (FIG.3C). At 600 °C the initial reaction rate closely matched that of CO₂ but the capacity was substantially higher. For the lithium-sodium borate, the CO₂ in the melt was in equilibrium with the CO₂ in the gas stream resulting in a gradual decrease in capacity with CO₂ concentration. Similar to the sodium borate, for SO₂ the same ~11 mmol/g was reached for both 1 mol% and 0.5 mol%, 60 minutes under 0.1 mol% was insufficient for the complete reaction to take place. Also, the reaction with CO₂ was reversed on exposure to nitrogen but SO₂ was retained. At 700 °C (FIG.3D) the capacity for CO₂ was lower as the release reaction became more favorable while for SO₂ a similar uptake profile was observed but with a second slower process occurring at high loadings resulting in a gradual increase beyond that seen at 600°C. Again, without wishing to be bound by any theory, the release profile at 700 °C confirms the irreversibility of SO₂ uptake with both sodium and lithium-sodium borate. Acid Gas Mixtures In many real systems, multiple acid gases exist together and with societies growing environmental awareness it is expected that future facilities will require tight control of all acid gas emissions. Therefore, a mixture of 10 mol% CO₂ and 0.5 mol% SO₂ was examined, which resembles a worst-case scenario for a power plant burning high sulfur bituminous coal. To gain an understanding of the influence of each acid gas and possible interactions between the two, a number of uptake experiments were performed including each gas individually, 10 mol% CO₂ (CO₂) and 0.5 mol% SO₂ (SO₂), and both gases together 10 mol% CO₂ and 0.5 mol% SO₂ (CO₂ & SO₂). In some variants these were followed by a change to another mixture of acid gases. Such as, 10 mol% CO₂ followed by 0.5 mol% SO₂ (CO₂→ SO₂), 0.5 mol% SO₂ followed by 10 mol% CO₂ (SO₂ → CO₂), and finally, 10 mol% CO₂ followed by the mixture of 10 mol% CO₂ and 0.5 mol% SO₂ (CO₂ → CO₂ & SO₂). The difference between (CO₂ → SO₂) and (CO₂ → CO₂ & SO₂) is that in the former the partial pressure of CO₂ changes whereas in the latter it does not. Subsequently the non-CO₂ acid gas sorbent was exposed to nitrogen in the release step, in the cases without a displacement step a dashed line connects the uptake and release profiles. The loading is reported on a mass rather than molar basis since in the case of mixtures it cannot be known for certain which gas reacted and hence which molecular weight to apply. For the non-CO₂ acid gas sorbent Na_xB_1-xO_1.5-x (x = 0.75) at 600 °C (FIG.4A), CO₂ rapidly reacted and reached full capacity within just a few minutes. The concentration of SO₂ was 20 times lower so the reaction was slower for SO₂ individually, but the loading approached the full capacity seen in FIG.3A within 60 minutes. For the mixture of both gases the loading closely matched that of CO₂ initially but then continued to increase. However the capacity of SO₂ individually was not reached with 60 minutes, suggesting that CO₂ was being slowly displaced by SO₂. The same was true when the non-CO₂ acid gas sorbent was first loaded with CO₂ and then exposed to SO₂, and when loaded with CO₂ and then exposed to the mixture. These three cases were similar because at 600 °C the change in partial pressure of CO₂ does not result in significant release of CO₂. Under release conditions at 600 °C desorption was not favorable for either gas. CO₂ loading dropped slightly but most other variations resulted in no significant release. Without wishing to be bound by any theory, in the case of SO₂ → CO₂ the loading remained approximately constant confirming that SO₂ reacts irreversibly with the non-CO₂ acid gas sorbent and cannot be displaced by CO₂ in some embodiments. The results at 700 °C differed from those at 600 °C partly because the release of CO₂ is favorable at the higher temperature. In FIG.4B, the mixture of gases first follows the path of CO₂ individually then deviates and approaches the capacity of SO₂ individually. In the case of CO₂ → SO₂ a slight drop in loading was seen as CO₂ was released before the loading increased with the uptake of SO₂. In some cases, the rate of uptake of SO₂ is faster for CO₂ → SO₂ than the cases SO₂ & CO₂ and CO₂ → CO₂ & SO₂. The presence of CO₂ slows the displacement reaction as the carbonate product remains stable. As seen at 600 °C CO₂ does not displace SO₂ in the SO₂ → CO₂ variation. Under release conditions CO₂ individually was quickly released while SO₂ was not released. The change in loading for each variation therefore indicates the relative proportion of CO₂ and SO₂ captured. The lithium-sodium borate (Li_0.5Na_0.5)_xB_1-xO_1.5-x (x = 0.75) differed from the sodium borate in that the capacity was greater, the CO₂ reaction was reversible at at least some temperatures, and the reaction products were liquids. At 600 °C, FIG.4C, the mixture first tracks the loading of CO₂ individually but then quickly displaces this CO₂ with SO₂ and tracks the loading of SO₂ individually. Without wishing to be bound by any theory, it is believed that the carbonate ion stabilized in the melt through coordination with free lithium and sodium ions and were more easily displaced than the solid sodium carbonate crystals in the case of the sodium borate. Therefore, each variation the capacity reached that of SO₂ individually regardless of the presence of CO₂ or original loading. The complete displacement of CO₂ by SO₂ was supported by the release profiles in which show the release of CO₂ individually but no release for any other variant. Without wishing to be bound by theory, it is believed that at 700 °C (FIG.4D), the capacity for CO₂ decreased due to more favorable release conditions but otherwise the profiles for each variation are similar to those at 600 °C. Oxides of Sulfur, SO_x FIG.3A suggests that for Na_xB_1-xO_1.5-x (x = 0.75) at 600°C the reaction proceeded in a similar manner for both SO₂ and CO₂. It is known that for CO₂ the general reaction proceeds with conversion to sodium metaborate (NaBO₂, x = 0.50) and sodium carbonate (Na₂CO₃),

where 0.50 < x < 1 Equation 1 For the case where this initial composition of the sodium borate is x = 0.75 the stoichiometry of the reaction with conversion to x = 0.50 can be written as, Na₃BO₃ + CO₂ → NaBO₂ + Na₂CO₃ Equation 2 The similarity between the uptake profiles at 600 °C implies the SO₂ reaction is analogous, Na₃BO₃ + SO₂ → NaBO₂ + Na₂SO₃ Equation 3 Assuming this is true, the complete reaction should correspond to a capacity of 501 mg/g. FIG.5A, shows the loading as a function of temperature for Na_xB_1-xO_1.5-x (x = 0.75) under 1 mol% SO₂ with a gradual temperature ramp of 5°C/min. In addition the capacity under isothermal uptake conditions from FIG.3, above, is represented by dots and the dashed lines show the theoretical capacity for a given reaction, for example (x = 0.50, Na₂SO₃) corresponds to Equation 3, where the borate reacts to x = 0.50 (NaBO₂) and the sulfurous product Na₂SO₃. The difference between the temperature ramp and the isothermal capacity is due to relatively slow kinetics under 1 mol% SO₂. FIG.5A, shows the capacity at 600°C was slightly below but close to that predicted by Equation 3 supporting the view that this is the primary reaction mechanism. In addition, XRD analysis, FIG.5B, revealed the dominant peaks corresponded to sodium metaborate (NaBO₂) and sodium sulfite (Na₂SO₃). However, at 700°C the isothermal capacity exceeded this capacity which cannot be explained by Equation 3. Without wishing to be bound by any theory, a possibility is the occurrence of the following decomposition reaction which has been known to occur at around 700°C, 4Na₂SO₃ → 3Na₂SO₄ + Na₂S Equation 4 Equation 4 explains the observation of sodium sulfate (Na₂SO₄) rather than sodium sulfite (Na₂SO₃) by XRD after reaction at 700°C, FIG.5B. To explain the increased capacity, without wishing to be bound by any theory, consider that sodium sulfide, Na₂S, may have reacted further with SO₂ with the involvement of platinum, from the platinum pan or platinum substrate, to generate platinum sulfide (PtS) and more sodium sulfate (Na₂SO₄), Na₂S + 2SO₂ + 2Pt → 2PtS + Na₂SO₄ Equation 4B Without wishing to be bound by any theory, this reaction could raise the capacity to ~630 mg/g and provide an explanation for the slower second increase in loading observed in the uptake experiments, FIG.3B, furthermore platinum sulfide peaks observed by XRD after reaction at 700°C, FIG.5B. Without wishing to be bound by any theory, similar reactions might also explain the performance of the lithium-sodium borate, FIG.5C. However, at 600 °C the capacity exceeded that predicted by the equivalent of Equation 3 suggesting that at both temperatures considered the equivalent of Equation 4 played an important role. Without wishing to be bound by any theory, the observation of capacity even greater than predicted by Equation 4 for the lithium-sodium borate under isothermal uptake at 700°C could be due to the formation of poly-sulfides or the conversion of lithium borate to compositions less than x = 0.50, for example x = 0.25 (Li₂B₄O₇), which has been proposed as a possible product of the reaction between tri-lithium borate (Li₃BO₃) and CO₂. XRD at 25°C after reaction at 600°C, FIG.5D, supports the reaction to sulfate products with peaks corresponding to sodium sulfate (Na₂SO₄), lithium-sodium sulfate (LiNaSO₄), and lithium metaborate (LiBO₂). The expected instability of lithium sulfite (Li₂SO₃), and the absence of any sodium borate peaks suggest that sodium is the dominant alkali metal in the reaction with SO_x. Without wishing to be bound by theory, it is thought that Equation 3 and Equation 4 both occur as written with sodium taking part in the reactions. Subsequently sodium sulfate forms and some of the lithium present in the melt coordinates with the sulfate to form lithium-sodium sulfate. Sodium sulfate melts at ~880°C, which suggested for Na_xB_1-xO_1.5-x (x = 0.75) the SO₂ reaction mechanism is similar to CO₂, in that the gas reacted with the liquid non-CO₂ acid gas sorbent to form solid precipitants. However, for the lithium-sodium borate, in some embodiments, this may not be the case. With CO₂ the lithium-sodium borate, (Li_0.5Na_0.5)xB_1- _xO1_.5-x (x = 0.75), forms a eutectic such that both the borate and the carbonate products are in the liquid phase above ~500°C. In the case of SO₂ HTXRD showed that at 600 °C no peaks corresponding to an alkali metal borate were present, suggesting these species exists in the liquid phase. Only the lithium-sodium sulfate (LiNaSO₄) phase remained a solid crystal at ~600 °C, but at 700 °C this compound was also brought into the melt such that all reaction products with SO₂, with the exception of platinum sulfide, were liquids at 700 °C, similar to the case with CO₂. The reactions and mechanisms proposed in this example may have important ramifications on the design of high-temperature carbon capture facilities and will be discussed further below. However, a discussion is included here of two expected phenomena of interest in the oxidizing environment of real exhausts containing SO_x. First, without wishing to be bound by theory, sodium sulfide is unlikely to be stable in the presence of an oxidizing agent, for example, Na₂S + 2 O₂ → Na₂SO₄ Equation 5 Hence, corrosion of the reactor vessel by sulfurization may be less likely than implied by the formation of transition metal sulfide in the above examples. And second, at high temperatures SO₂ may react with oxidizing agents to SO₃, which the latter typically comprises 0.1 to 3 mol%, SO₂ + ½ O₂ ←→ SO₃ Equation 6 Although not studied explicitly mentioned in this example, sulfur trioxide (SO₃) is contemplated to be efficiently captured by a more direct reaction with the molten alkali metal borates (A₃BO₃) to form sulfates, (A2SO₄) bypassing the formation of sulfites (A₂SO₃) and sulfides (A₂S), A₃BO₃ + SO₃ → ABO₂ + A₂SO₄ Equation 7 Hydrogen Sulfide, H₂S Hydrogen sulfide presents an interesting parallel to the oxides of sulfur. As with SO_x the interaction between the basic non-CO₂ acid gas sorbent and the acidic gas was strong, which may result in the efficient removal of the gas. FIG.6A shows the weight change of the sodium borate Na_xB_1-xO_1.5-x (x = 0.75) under a temperature ramp of 5°C/min and 1 mol% H₂S. Note that, in some cases, limited experiments were carried out with H₂S due to its propensity to damage the instrumentation used in the uptake experiments. However, the results for the sodium borate may be sufficient to give some useful insight into the reaction mechanism. Unlike with CO₂ and SO₂, the reaction with H₂S began at ~430 °C much lower than the melting point of the non-CO₂ acid gas sorbent (~570 °C). Between 550 °C and 650 °C the loading plateaus around 350 mg/g before increasing further as the temperature was increased. The typical reaction between metal oxides and H₂S involves the formation of metal sulfides and water/steam, for example, Na₃BO₃ + H₂S → NaBO₂ + Na₂S +H₂O Equation 8 Without wishing to be bound by any theory, the theoretical capacity of this reaction is only 126 mg/g, which was quickly surpassed in the uptake experiment, but even complete conversion to x = 0, with reaction products Na₂S and B₂O₃, would only give a theoretical capacity of 283 mg/g. However, the formation of poly-sulfides or sodium platinum sulfide ( Na₂PtS₂) with conversion of the alkali metal borate to x = 0.50 may explain the loading in the range 550°C to 650°C, for example, Na₃BO₃ + 2H₂S → Na₂PtS₂ + H₂O + H₂ + NaBO₂ Equation 9 which was supported by XRD, FIG.6B, revealing peaks that after reaction at 600°C can ascribed to Na₂S, NaBO₂, and Na₂PtS₂. In certain embodiments above 650°C, the reaction may proceed to a conversion less than x = 0.50, at the extreme x = 0, which would give a theoretical capacity of ~1700 mg/g. In some cases, no uptake experiments were carried out with the lithium-sodium borate (Li_0.5Na_0.5)_xB_1-xO_1.5-x (x = 0.75); however, XRD revealed a reaction similar to Equation 9 is likely with products including Na₂PtS₂ and Li₆B₄O₉. Oxides of Nitrogen, NO_x The oxides of nitrogen present a complex and challenging case to study. Firstly, gas phase chemistry plays an especially important role as at the high temperatures of interest NO₂ decomposes by the equilibrium reaction, Equation 10

resulting in a mixture that is only 5 to 10 mol% NO₂ at capture conditions. Secondly, the expected nitrate and nitrite products bring complexity in the multiple consecutive and reversible reactions that may occur. Thirdly, as with H₂S, in some embodiments, limited experiments could be carried out with NO_x due to damage inflicted on equipment. Despite these challenges, meaningful conclusions can be drawn from the interaction between the molten alkali metal borates and NO_x emitted from high temperature sources. FIG.7A shows the weight change of the sodium borate Na_xB_1-xO_1.5-x (x = 0.75) under a temperature ramp of 5°C/min and 1 mol% NO₂. Uptake began as low as 300 °C and reached a peak at 600 °C before release becomes favorable and the loading decreases, at ~700 °C a negative loading was observed, indicating a loss of mass from the original sodium borate. Without wishing to be bound by any theory, sodium nitrate and nitrite are liquids above ~300 °C, and may catalyze their own reaction by providing a liquid surface capable of reacting rapidly with the solid sodium borate at temperatures much lower than its melting point, as is the case in molten nitrate promoted CO₂ capture using metal oxides. Decomposition and vaporization of the nitrates and nitrates is known to occur simultaneously at temperatures above 600 °C, which could explain the loss of mass above ~700 °C. Based on theoretical capacity, the reaction with NO_x appears to have the stoichiometry close to, Na₃BO₃ + NO₂ + NO → NaBO₂ + 2NaNO₂ Equation 11 though it is recognized that in practice it is likely a large number of gas and liquid phase reactions lead to the net reaction given by Equation 11. The observation of peaks corresponding to sodium nitrite (NaNO₂) and sodium metaborate (NaBO₂) after exposure to NO₂ at 600 °C, FIG.7B, supported this net reaction for certain embodiments. However, in some embodiments, unreacted tri-sodium borate (x = 0.75), and partially reacted di-sodium borate (x = 0.66) were also observed indicating that the reaction did not proceed to the same extent in the tube furnace. After reaction at 800 °C, the peaks ascribed to sodium nitrite (NaNO₂) were no longer present leaving a mixture of tri- sodium borate (Na₃BO₃) and di-sodium borate (Na₄B₂O₅). Decomposition to Na₄B₂O₅ has a theoretical mass loss of 243 mg/g, therefore the mixture of Na₃BO₃ and Na₄B₂O₅, which may explain the observed loss of ~150 mg/g. The decomposition of sodium nitrite involves a number of reactions including the evolution of gaseous N₂, O₂, and NO, and solid Na₂O, which would recombine with the borate melt, in addition to vaporization. Isothermal uptake and release were demonstrated for some embodiments in FIG.7C at 600 °C without the mass loss associated with higher temperatures. As with other acid gases the behavior of lithium-sodium borate was similar to sodium borate, as demonstrated by the temperature ramp in FIG.7D. The maximum loading was lower, and the reaction did not go to completion, but significant uptake was observed even at 1 mol% NO₂. Without wishing to be bound by any theory, as with sulfates/sulfites, the lithium nitrates/nitrates were less stable than their sodium counterparts making it likely that sodium was the dominant alkali metal involved in the above reactions, with lithium preferentially interacting with the borate species. The understating developed above may influence the design of high-temperature carbon capture systems. The strong interaction between the molten alkali metal borates and the acid gases demonstrate that a sorber designed for carbon capture may capture not just CO₂ but any other acid gases (e.g., non-CO₂ acid gases) present. This could represent an opportunity to capture multiple acid gases in a single sorber, or a challenge to manage various corrosive or hard-to-handle reaction products. The distinction between opportunity and challenge lies in design, which will be the topic of this section of the Example. One of the principal advantages of the molten alkali metal borates is their fluidic nature, which may provide easy transfer between sorber and desorber at high temperatures, as depicted in FIG.8, for some embodiments. Without modification, considering the plots in FIG.8, two outcomes may be possible after capture of acid gases other than CO₂, either their release into the CO₂ product stream in the desorber, or their accumulation in the system until the non-CO₂ acid gas sorbent needs to be replaced. Note that CO₂ is in excess in the sorber resulting in a relatively low loading of other acid gases. Therefore, without wishing to be bound by any theory, it is not expected that their presence will significantly interfere with the pumping or fluidity of the bulk non-CO₂ acid gas sorbent, unless they accumulate. In many cases, the reaction with SO_x is irreversible at reasonable temperatures; however, the reaction with NO_x was easily reversed upon pressure-swing. Therefore, sulfurous products will be retained after the desorption step while products of the NO_x reaction will be released into the CO₂ product stream. Gaseous release from NO_x products at less than 700 °C comprise N₂, O₂, and NO, which may be acceptable in the product stream in small quantities. To reduce the vaporization of nitrates/nitrites and hence loss of alkali metal from the system, it was desirable to maintain desorption temperatures less than 700 °C. The loss of alkali metal from the system may slightly reduce the mixing ratio, x, of the molten alkali metal borate circulating between sorber and desorber. However, the mixing ratio could be raised by alkali metal hydroxide/carbonate addition. If loses are small and predominantly sodium rather than lithium, which is expected, this approach can be both simple and cost effective. A different strategy may be useful to handle sulfurous products as these may build-up in the system. One option would be to include a purge stream and continually replenish the non-CO₂ acid gas sorbent. However, the nature of the molten alkali metal borates could allow for not only the simultaneous capture of multiple acid gases but also their efficient separation. Since the molten alkali metal borates are liquids and the sulfurous products are typically solids any number of liquid-solid separation techniques could be applied to a slip stream of the circulating non-CO₂ acid gas sorbent, which would separate out the sulfurous compounds at high temperatures, as schematically depicted in FIG.8. As the density difference between the melt and the sulfurous products is relatively small, filtration may outperform gravitational methods of separation. For example, cross-flow filtration with a metal mesh separator applied to a slip stream downstream of the desorber pump may be a suitably simple and robust method at the high temperatures involved. A large mesh size would reduce pressure drop and allow for a modest amount of solids recirculation. Once upconcentrated, the sulfurous compounds could be further refined and purified under ambient conditions and made into marketable products. Several options exist including some at high temperatures which would minimize thermal loses. However, it is likely that the value of lithium relative to all other species will dictate the treatment method. One option would be to contact the concentrated sulfate stream with limewater, (Ca(OH)₂(aq)), as schematically illustrated in FIG.8. Without wishing to be bound by any theory, in the aqueous phase at ambient temperatures the sulfurous species would precipitate calcium sulfate (CaSO₄), for example, Ca(OH)_{2 (aq)} + NaLiSO_{4 (aq)} → CaSO_{4 (s)} + NaOH_(aq) + LiOH_{(aq )} Equation 12 The resultant gypsum (CaSO₄•2H₂O) could be sold as is common practice in the industry today, and the remaining ions in solution, which may include some borate species but more importantly valuable lithium ions, could be returned to the high temperature system. Evaporation of the water required for dissolution would leave predominantly alkali metal hydroxides which would return the non-CO₂ acid gas sorbent to its original mixing ratio, x. Assuming the reactor vessel can be protected from sulfurization, a similar process to that described for SO_x may be appropriate for simultaneous H₂S capture and separation. Solid Na₂S may be filtered and treated. As with sulfates, treatment would depend on the desired sulfurous product, but to ensure recovery of the alkali metal and borate species the reaction with oxygen to generate sulfates for subsequent treatment may be preferable. In the case of a reducing environment comprising no oxidizing agent will be present to protect the reactor vessel from sulfuization, as was the case in the oxidizing environment. In existing facilities that handle H₂S, particularly at high temperatures, sulfurization remains a major problem. Indeed, this is the primary motivation for pre-treatment in refineries and gas-sweetening facilities. Sulfurization can be subdued by material selection and the formation of a thin protective metal-sulfide layer. This and other corrosion prevention techniques could allow for the removal of H₂S by the molten alkali metal borates without undesirable reaction with the metals present in the sorber vessel walls or packing. Having said this, it is contemplated that upstream desulfurization, for example natural gas sweetening, will remain important to future carbon capture facilities operating under a reducing environment. Comparison with Others The conceptual designs described elsewhere herein may resemble some of the existing strategies in use for amine and calcium looping systems which, in some cases, represent the state-of-the-art in low and high temperature carbon capture, respectively. However, the molten alkali metal borates present a number of advantages in the context of dealing with acid gas impurities, which are briefly described below. In certain embodiments, SO_x react with amines to form dissolved sulfites/sulfates in the aqueous phase; however, the inability to upconcentrate these species requires that a large proportion of the recirculating amine solution be regularly purged for treatment. A number of options exist, with thermal reclamation, amines evaporation and recovery, being the most established. However, this approach is usually only cost effective with upstream flue gas desulfurization, since thermal reclamation results in amine losses, and presents a relatively large energy penalty and contaminates the semi-solid product. In some embodiments, NO_x also react with amines, forming dissolved nitrites/nitrates and nitrosamines/nitramines. Depending on the amine this absorption can result in modest removal of NO_x to near complete removal. While these reactions may provide some benefit in NO_x reduction the net effect is generally negative due to the health risks associated with some nitrosamines, which will be present in the solid product, and the relatively high cost of amines. As mentioned elsewhere herein, amines may be well suited to H₂S capture, in some cases, but not for high-temperature applications as described herein, such as pre-combustion carbon capture and hydrogen production. For appropriate comparison with a high- temperature non-CO₂ acid gas sorbent, we consider calcium oxide and the calcium looping process. Calcium oxide may also remove SO_x from the exhaust stream. However, in calcium looping, CaO, CaCO₃ and CaSO₄ are all solids and cannot be easily separated, requiring the regular purging in of the system. The situation is worsened by calcium sulfates propensity to block internal pores in the solid non-CO₂ acid gas sorbent, reducing its capacity for CO₂. Calcium compounds pervasiveness and low cost partly make up for this shortcoming but the outcome is not ideal. In reducing environments, calcium oxide reacts with hydrogen sulfide (H₂S) to form calcium sulfide (CaS), which is also purged as the non-CO₂ acid gas sorbent degrades. Without wishing to be bound by any theory, although calcium oxide has no propensity to react with NO_x, the use of oxy-combustion to generate a large portion of the plants power results in marginally lower NO_x emissions when compared to a reference power plant. However, these emissions would still be unacceptably high and downstream NO_x scrubbing would be required. Conclusions The interaction between the various acid gases (e.g., non-CO₂ acid gases) present and the non-CO₂ acid gas sorbent designed for carbon capture is a key challenge for the state-of- the-art of carbon capture, and a major stumbling block for less mature technologies. In this example and elsewhere herein, it has been demonstrated that the molten alkali metal borates may largely overcome this pitfall and do so in a way that may outperform both amines and calcium looping. This is not to say that challenges do not exist. The importance of material selection, specifically the requirement that vessels and lines containing sulfides be resistant to attack by sulfurization has been demonstrated. It is noted that excess oxygen is desirable in this regard as it will help to suppress the reaction pathway to sulfide formation, as such high- temperature reducing environments rich in H₂S should be minimized, in some cases, with upstream treatment as is common practice in industry today, for example natural gas sweetening. It is also noted that temperatures be limited to ~700°C to minimize vaporization of nitrate/nitrite species in some cases involving non-acid gas H₂S. However, the net outcome leans heavily towards opportunity. The strongly basic nature of the molten alkali metal borates mean that acid gases can be removed at the low concentrations and mixtures relevant to real systems. The fluidic nature of the molten alkali metal borates allows for designs that take advantage of the typically solid sulfurous products for their efficient separation at high temperatures. When compared to the options available to amines and calcium looping the, designs proposed for the molten alkali metal borates appear superior, bolstering the advantages already afforded to this new class of non-CO₂ acid gas sorbent for carbon capture. Indeed the molten alkali metal borates and associated system designs and mehtods may prove sufficiently efficient to generalize carbon capture to the broader challenge of acid gas capture. EXAMPLE 2 This example describes the process of regenerating sorbents using steam to remove acid gases (e.g., carbon dioxide) from the sorbent. It also describes how regenerating a sorbent may be done in many cycles (e.g., cyclically) to effect multiple iterations of sorbent regeneration. Experimental Setup of Bench Scale Experiments Bench scale experiments were designed as follows. These bench scale experiments may guide in the industrial scale design of reactors, such as those described in the prophetic designs in Example 3. Nickel tubes (Nickel 200/201, Magellan Metals) with ½” outside diameter and 0.41” (1 cm) inside diameter were cut to size and bent into the desired shape with a tube bender to form tubular reactors. Each tubular reactor contained a kink such that the molten sample spread evenly along the base of the tube and was contained inside the furnace, with approximate dimensions shown in FIG.12A. The tubes were inserted into a tube furnace (OTF-1200, MTI Corp), externally insulated with quartz wool and aluminum foil, and connected to upstream and downstream pipework with stainless steel compression fittings. Upstream a digital mass flow controller (GFC17, Aalborg) and mass flowmeter (XFM17, Aalborg) provided a steady flow of CO₂ at various concentrations (Airgas). For each CO₂ concentration the flowmeter was calibrated against a flowmeter with adjustable gas settings (00412ML, ColeParmer). Pressure gauges (DPG409, Omegadyne) were located upstream and downstream of the tubular reactor. Downstream a filter (F504-02DHSS, Parker Watts) was chilled externally with ice to act as a separator and remove any water vapor, subsequently the CO₂ concentration was measured by infrared detection (CM-0154, CO₂ Meter). Sorbent Regeneration The regeneration of sorbents used for acid gas capture is an important part of processes designed to reduce emissions. The examples provided herein primarily focus on the problem of global warming and CO₂ emissions, but the processes and systems described herein can be extended to other acid gasses, for example SO_x and NO_x, and other global challenges, for example acid rain. The regeneration of sorbents used for the capture of acid gases, in particular carbon dioxide, from industrial streams may find application in the energy and chemicals industries. Options for regeneration include temperature swings, partial pressure swings, and electric potential swings. In each case, capture is carried out at one set of conditions, for example at a low temperature, and the regeneration is carried out in a different environment, separated either spatially or temporally, under a different set of conditions, for example a higher temperature. Existing process designs are often inefficient because they fail to efficiently utilize the energy content of the various streams involved. In part this is related to limitations inherent in the materials used for capture. However, materials described elsewhere herein can provide highly efficient regeneration processes. The inventors have recognized and appreciated that an important improvement is to operate the system isothermally or near-isothermally at high temperatures and use steam to reduce the partial pressure of acid gas in the regenerator (e.g., the desorber) to drive the regeneration, subsequently condensing the steam from the mixture of acid gas and steam to generate a high purity acid gas product. In this way the energy content of both the separated acid gas and the steam used to reduce the partial pressure can be recovered in a downstream heat exchanger. Without wishing to be bound by any theory, it is believed that the steam does not interact with the sorbent per se but, rather, provides an entropic driving force for the release of an acid gas by reducing the partial pressure in the release environment. Unlike other gases which may be used as sweep gases to reduce the partial pressure (e.g., N₂, argon), steam is easily separated from the acid gas in a condenser. Molten alkali metal borates may be used a sorbent throughout the regeneration process. These molten alkali metal borates may possess many features that make them promising sorbents for carbon capture. One of these features is their high working capacity under a change in CO₂ partial pressure. For sources of CO₂ near ambient pressure, pressure swings can generally be driven either by pulling a vacuum, which tends to be highly inefficient and difficult to maintain at scale, or with a sweep gas. Sweep gases (e.g., N₂, argon) can dilute the product rather than upconcentrate it and therefore have found limited use in low temperature carbon capture systems. However, at high temperatures a convenient, advantageous sweep gas is found in steam, since steam readily condenses once the H₂O/CO₂ mixture is cooled after standard heat recovery units. FIG.12B, schematically illustrates a block diagram demonstrating this concept. The equipment used in the bench scale experiment is shown in bold with the analogous industrial scale process units in parenthesis and italics. In the capture step the CO₂ containing stream is fed into the tubular reactor and the CO₂ is removed. As depicted in FIG.12C, using 20 ml/min of 20% CO₂ removed ~90% of the incoming stream. In the release step the feed is switched to steam which reduced the partial pressure of CO₂ in the reactor extracting CO₂ from the sorbent. Subsequently the combined H₂O/CO₂ mixture was cooled and the steam condensed in a separator to form a pure CO₂ stream. The cycle in schematically illustrated in FIG.12C is part of a series of cycles shown in the inset of FIG.12C that demonstrates the repeatability of capture and release by this method over many cycles. A high temperature carbon capture unit can be operated isothermally and at ambient pressures without the need for oxy-combustion driven release as commonly practiced with the existing method of calcium looping. Advantageously, the energy content of the H₂O/CO₂ mixture may be recovered in a heat recovery steam generator (HRSG) prior to separation in the condenser thereby recovering valuable high quality heat during both capture and release, resulting in a highly energy efficient process. Without wishing to be bound by any theory, the steam does not interact with the sorbent per se but provides an entropic driving force for the release, the same way a flow of pure nitrogen does. Therefore, more convenient experiments that use nitrogen are directly comparable to those that use steam as a sweep gas. The process described herein can be highly efficient in separating and regenerating acid gases from industrial streams. The process design applied to a natural gas combined cycle (NGCC) power plant with carbon capture is presented in subsequent prophetic examples. In an industry when vast effort and capital are deployed to improve efficiency by fractions of a percentage point, the process described herein is expected to substantially reduce the energy penalty for the removal of CO₂ as compared to existing systems in this field. Other applications of this process design exist for other fuels, such as coal, oil, or biomass, or chemical processes which release CO₂ including smelting of metals, the production of cement, and steam methane reforming for hydrogen production. In these cases, similar efficiency gains are expected. Molten sorbents, specifically molten alkali metal borates, are described in this example and elsewhere herein. However other sorbents may be used, such as solid alkali metal borates. The molten sorbents may have high working capacities under the pressure swings that occur during regeneration (e.g., the introduction of steam, release of acid gases from the sorbent). In addition, the molten sorbents can be very stable under high temperature and isothermal operation conditions, which can provide efficient recovery of heat. The fluidic nature of the molten sorbents can provide efficient heat exchange, seamless transfer between capture and release environments, and the ability to compress to higher pressures. FIGS.12-13 detail the underlying concept and the experiments carried out to demonstrate a functional system, while FIG.14 shows how the reactor may be spatially separate with continuous circulation between a dedicated capture and release environments. This is in contrast to the fixed bed in FIG.12D where capture and release are separated temporally in a single reactor. As described in more detail in Example 3, FIGS.15A-15B present block diagrams of the process applied to a natural gas combined cycle and a steam methane reforming system, while FIGS.16-18 schematically illustrate a more detailed picture of the process design for a natural gas combined cycle, a steam methane reforming system, and a cement production plant, respectively, and will be described further below. Sorbent Regeneration Performance The performance of the sorbents was analyzed by investigating the breakthrough behavior of the sample loaded inside the tubular reactor. Breakthrough behavior may be determined as follows. An empty tube may be filled with nitrogen gas and a stream of CO₂ may be flowed through the tube, as schematically illustrated in FIGS.12A and 12D. A CO₂ detector at the end of the tube may measure nitrogen for a time, and as the nitrogen is pushed out of the tube, CO₂ may then reach the detector, or “breakthrough,” and be detected by the CO₂ detector. In some cases, a “plug flow” may occur as a sudden change, but in practice a more gradual breakthrough may be observed, as shown in the “control” plot in FIG.12D. When the tube contains a sorbent, as in FIG.12D in the “sample” plot, the breakthrough is delayed because the sorbent can capture some or all the incoming CO₂ and the sensor continues to detect only nitrogen. However, after some time, the sorbent may reach its capacity for CO₂ and the CO₂ pushes all the way through the tube to reach, or breakthrough to, the CO₂ detector. The sample (e.g., the sorbent) was weighed, inserted into the tube, then pre-treated at 800 °C under a flow of N₂ to melt the sample and remove any residual H₂O/CO₂. Pre-treatment was considered complete once the composition of the stream leaving the system dropped below ~0.1% CO₂ at 800 °C. At time = 0, the gas flow was switched from N₂ to CO₂ while monitoring the outlet CO₂ concentration. FIG.12D shows a plot where the dimensionless concentration is the outlet concentration divided by the inlet. A control experiment flowing under conditions of no- capture, for example at room temperature, is compared to CO₂ capture conditions where breakthrough is delayed. The area between the non-capture control and the capture experiment gave the sorbent’s capacity, which was calculated in mmol of CO₂ per gram of sorbent (mmol/g). Outside of FIG.12D, breakthrough profiles may be presented as bed volumes of CO₂ normalized by sample mass. The bed volume is determined from the control experiment by integrating the area bound by the x-axis at time = 0, dimensionless concentration = 1, and the breakthrough curve for a given flowrate. To avoid plotting a control in each case, one bed volume, i.e. the volume of the system, was then subtracted. As such the area bound by the x- axis at time = 0, dimensionless concentration = 1, and the breakthrough curve for a given flowrate gives the CO₂ capacity in breakthrough plots other than those shown in FIG.12D. Bed volumes can be converted into bed volumes of CO₂ through multiplication with the inlet CO₂ concentration, and then normalized by the sample mass loaded into the tube to give normalized bed volume of CO₂ (1/g). As hygroscopic samples lose mass during the pre- treatment step, the mass loss can be determined by thermogravimetric analysis (Q-50, TA Instruments) and accounted for in the normalization and capacity calculations. Comparison of Steam and Nitrogen in Sorbent Regeneration Performance Next, it was shown that steam can be used to effect the regeneration of a sorbent in a manner similar to an inert gas, such as nitrogen. FIG.13 illustrates the performance of steam as a sweep gas compared to nitrogen gas. Before time zero the sample (e.g., the sorbent) spent 60 mins under 20% CO₂ and is considered to be fully loaded with CO₂. At time zero mins the gas flow was switched, either to nitrogen or steam (water injection into the furnace). In both cases the loading of CO₂ decreases in a similar manner suggesting the method of release is similar for both sweep gases. This demonstrates that steam can be used to effect the entropy-driven release of acid gas from the sorbent. That is to say, without wishing to be bound by any theory, the steam does not interact with the sorbent but provides an entropic driving force similar to nitrogen. But unlike nitrogen, steam can be readily condensed and removed from the acid gas as described previously and elsewhere herein. EXAMPLE 3 The following provides prophetic examples of processes for sorbent regeneration. In some cases, sorbent regeneration can be coupled with industrial processes. Continuous Circulation of Sorbent between a Dedicated Capture and Release Environments As schematically illustrated in FIG.14, the CO₂ rich stream can be contacted with the sorbent in the capture environment resulting in a treated CO₂ lean stream and a sorbent loaded with CO₂. The CO₂ loaded sorbent can be pumped to the release environment via a transfer pump and a heat exchanger. The heat exchanger may contact the loaded sorbent with the unloaded sorbent. The aim of the heat exchanger is to maintain a similar temperature in both the capture and release environments. In certain cases, this alone may not be enough to equalize the temperatures in the capture environment and release environment. In some cases, to circumvent this issue, one option would be to locate the release environment inside the capture environment. For example, the release environment may comprise tubes that run through the capture environment. In the release environment the CO₂ loaded sorbent is contacted with steam and the CO₂ can be stripped from the sorbent while the unloaded sorbent can be returned to the capture environment via a transfer pump and a heat exchanger. The steam CO₂ mixture can then be cooled, and CO₂ can be separated from the water as the latter condenses. The CO₂ may then be sent for compression and export while the water is raised to steam and the cycle repeats. Carbon Capture Using the Natural Gas Combined Cycle (NGCC) and the Steam Methane Reforming (SMR) with Sorption Enhanced Reformed (SER) At the plant level for a NGCC fuel, air may be fed into a gas turbine and hot flue gases may be produced. These hot flue gases can be passed into the capture block, as schematically illustrated in FIG.15A, along with steam to produce a CO₂-lean flue gas and a steam CO₂ mixture. The hot, CO₂-lean flue gas can then be used to drive a steam turbine with some steam being used to supply the capture block. The steam CO₂ mixture may also pass through a steam cycle as the CO₂ and steam are separated. For a sorption-enhanced reforming plant, the fuel (typically methane) can be sent straight into the capture/conversion block (schematically shown in FIG.12B and with more detail in FIG.17). Steam can be used both as a reactant and as a sweep gas (in separate vessels) to generate a hydrogen-rich stream and a steam/CO₂ mixture which can be separated after the secondary heat recovery steam generator (HRSG). An external steam supply may be required to supply sufficient steam, which may come from a neighboring power plant or a renewable source. A Detailed System Level Design of NGCC with Carbon Capture As shown in FIG.16, natural gas can be fed into the combustion chamber along with compressed air. The gas turbine may drive the compression via a shaft and may also supply energy to the generator for conversion into electricity. The hot flue gases can be used to generate steam (or supplement steam generation) and can be sent through the capture environment where the steam is contacted with the sorbent and CO₂ is removed. The flue gas may then pass the 1^st HRSG to generate further steam at various pressure levels (e.g., high, medium, low). These steam turbines can then generate electricity (as schematically shown in FIG.16) or may support the supply of steam sweep gas (not shown in the figure). The condensate can then return to the HRSG via a feed pump and a cold reservoir may be required as a heat sink. The sorbent may then pass to the release environment via a transfer pump to a heat exchanger where the steam sweep gas can be used to strip the sorbent of the CO₂. The sorbent can then be returned to the capture environment to complete the cycle while the steam/CO₂ mixture can be passed to a 2^nd HRSG to generate further steam at various pressure levels (e.g., high, medium, low). These steam turbines can generate electricity (as schematically shown in FIG.16) or may support the supply of steam sweep gas (not shown in the figure). In some embodiments, the 2^nd HRSG operates the same as the 1^st. As a final step the cooled steam/CO₂ mixture may pass through a condenser to recycle the condensate and generate a CO₂ stream ready for compression and export. A Detailed System Level Design for Steam Methane Reforming with Sorption-Enhanced Reforming with Carbon Capture Natural gas may be preheated in the 1^st HRSG, desulfurized, pre-reformed (i.e., converted to predominantly methane), and then further preheated in the 1^st HRSG before passing to the reactor (sorption-enhanced reformer), as schematically illustrated in FIG.17. Steam from the 1^st HRSG and the sorbent may also be sent to the reactor to convert methane into hydrogen and CO₂. As a result, excess steam and the hydrogen product may exit the reactor as gases while the CO₂ is removed with the sorbent as a liquid and passes to the release environment. The steam in the release environment may be used to release the CO₂ from the sorbent generating a steam/CO₂ mixture which passes through a 2^nd HRSG. As the temperature drops, the steam may be passed through a condenser to separate the condensate, which can be recycled via a feed pump, and the CO₂ product may be sent for compression and export. The steam generated can be used as the steam sweep gas and is supplemented by a supporting steam supply (e.g. a renewable source). The hydrogen and steam mixture may drive the 1^st HRSG and can be separated via a cooler, with the condensate recycled through a feed pump. To ensure a high purity hydrogen product a conventional pressure swing absorption (PSA) unit may be included with the off-gas returned to the release environment where further sorption-enhanced reforming would occur. The hydrogen may then be compressed for export. A Detailed System Level Design for Cement Production with Carbon Capture As schematically shown in FIG.18, raw material (e.g., limestone) can be fed into the raw mill and filtered to produce raw meal. The raw meal may then be pre-heated before being sent to the calciner where CO₂ is driven from the limestone to produce predominantly calcium oxide. The product can pass through the rotary kiln to generate a clinker which may be cooled in a clinker cooler and made ready for export. The process may be driven by fuel (typically coal, as one non-limiting example) which can enter both the rotary kiln and calciner and can be combusted in the presence of air. The air can then be used as the cooling medium in the clinker cooler and is therefore preheated before entering the rotary kiln and calciner. Typically, the hot flue gas then passes to the pre-heater but in the case of CO₂ capture the hot flue gas may first be used to generate steam in the steam sweep gas generator and passed through the capture environment to capture CO₂. The cleaned hot flue gas can then be passed through the pre-heater, raw mill, and filter as in the conventional process. To maintain the same level of pre-heating, additional fuel may be required. The CO₂-loaded sorbent can then pass through a transfer pump and heat exchanger to the release environment as described previously in the Examples. Supporting steam may be required for the release which may come from a neighboring power plant or renewable sources. The steam/CO₂ mixture can then be separated in a condenser with the steam recycled and the CO₂ compressed for export. While several embodiments of the present invention have been described and illustrated herein, those of ordinary skill in the art will readily envision a variety of other means and/or structures for performing the functions and/or obtaining the results and/or one or more of the advantages described herein, and each of such variations and/or modifications is deemed to be within the scope of the present invention. More generally, those skilled in the art will readily appreciate that all parameters, dimensions, materials, and configurations described herein are meant to be exemplary and that the actual parameters, dimensions, materials, and/or configurations will depend upon the specific application or applications for which the teachings of the present invention is/are used. Those skilled in the art will recognize, or be able to ascertain using no more than routine experimentation, many equivalents to the specific embodiments of the invention described herein. It is, therefore, to be understood that the foregoing embodiments are presented by way of example only and that, within the scope of the appended claims and equivalents thereto, the invention may be practiced otherwise than as specifically described and claimed. The present invention is directed to each individual feature, system, article, material, and/or method described herein. In addition, any combination of two or more such features, systems, articles, materials, and/or methods, if such features, systems, articles, materials, and/or methods are not mutually inconsistent, is included within the scope of the present invention. The indefinite articles “a” and “an,” as used herein in the specification and in the claims, unless clearly indicated to the contrary, should be understood to mean “at least one.” The phrase “and/or,” as used herein in the specification and in the claims, should be understood to mean “either or both” of the elements so conjoined, i.e., elements that are conjunctively present in some cases and disjunctively present in other cases. Other elements may optionally be present other than the elements specifically identified by the “and/or” clause, whether related or unrelated to those elements specifically identified unless clearly indicated to the contrary. Thus, as a non-limiting example, a reference to “A and/or B,” when used in conjunction with open-ended language such as “comprising” can refer, in one embodiment, to A without B (optionally including elements other than B); in another embodiment, to B without A (optionally including elements other than A); in yet another embodiment, to both A and B (optionally including other elements); etc. As used herein in the specification and in the claims, “or” should be understood to have the same meaning as “and/or” as defined above. For example, when separating items in a list, “or” or “and/or” shall be interpreted as being inclusive, i.e., the inclusion of at least one, but also including more than one, of a number or list of elements, and, optionally, additional unlisted items. Only terms clearly indicated to the contrary, such as “only one of” or “exactly one of,” or, when used in the claims, “consisting of,” will refer to the inclusion of exactly one element of a number or list of elements. In general, the term “or” as used herein shall only be interpreted as indicating exclusive alternatives (i.e. “one or the other but not both”) when preceded by terms of exclusivity, such as “either,” “one of,” “only one of,” or “exactly one of.” “Consisting essentially of,” when used in the claims, shall have its ordinary meaning as used in the field of patent law. As used herein in the specification and in the claims, the phrase “at least one,” in reference to a list of one or more elements, should be understood to mean at least one element selected from any one or more of the elements in the list of elements, but not necessarily including at least one of each and every element specifically listed within the list of elements and not excluding any combinations of elements in the list of elements. This definition also allows that elements may optionally be present other than the elements specifically identified within the list of elements to which the phrase “at least one” refers, whether related or unrelated to those elements specifically identified. Thus, as a non-limiting example, “at least one of A and B” (or, equivalently, “at least one of A or B,” or, equivalently “at least one of A and/or B”) can refer, in one embodiment, to at least one, optionally including more than one, A, with no B present (and optionally including elements other than B); in another embodiment, to at least one, optionally including more than one, B, with no A present (and optionally including elements other than A); in yet another embodiment, to at least one, optionally including more than one, A, and at least one, optionally including more than one, B (and optionally including other elements); etc. In the claims, as well as in the specification above, all transitional phrases such as “comprising,” “including,” “carrying,” “having,” “containing,” “involving,” “holding,” and the like are to be understood to be open-ended, i.e., to mean including but not limited to. Only the transitional phrases “consisting of” and “consisting essentially of” shall be closed or semi-closed transitional phrases, respectively, as set forth in the United States Patent Office Manual of Patent Examining Procedures, Section 2111.03.

Claims

CLAIMS What is claimed is: 1. A method, comprising: exposing a non-CO₂ acid gas sorbent, the non-CO₂ acid gas sorbent comprising a salt in molten form, to an environment containing a non-CO₂ acid gas such that at least a portion of the non-CO₂ acid gas interacts with the non-CO₂ acid gas sorbent and at least a portion of the non-CO₂ acid gas is removed from the environment.

2. The method of claim 1, wherein the salt in molten form comprises an alkali metal borate, M_xB_1-xO_1.5-x, wherein M is one or more alkali metals, B is Boron, O is Oxygen, and x is a number such that 0 < x < 1.

3. The method of claim 2, wherein the alkali metal comprises lithium (Li), sodium (Na), potassium (K), and/or a mixture of these.

4. The method of claim 3, wherein the alkali metal comprises Li and Na in equal amounts.

5. The method of any one of claims 1-4, wherein the non-CO₂ acid gas comprises sulfur monoxide (SO), sulfur dioxide (SO₂), nitrogen dioxide (NO₂), hydrogen sulfide (H₂S), sulfur trioxide (SO₃), nitric oxide (NO), nitrous oxide (N₂O), dinitrogen trioxide (N₂O₃), dinitrogen tetroxide (N₂O₄), dinitrogen pentoxide (N₂O₅), and/or carbonyl sulfide (COS).

6. The method of any one of claims 1-5, wherein the environment is at a temperature of at least 200 °C.

7. The method of any one of claims 1-6, wherein a plurality of non-CO₂ acid gases interacts with the non-CO₂ acid gas sorbent such that at least a portion of the plurality of non- CO₂ acid gases are removed from the environment.

8. The method of any one of claims 1-7, wherein captured non-CO₂ acid gas is released in the gas phase in a separate environment and upconcentrated.

9. The method of claim 8, wherein the release is driven, at least in part, by a change in partial pressure of the non-CO₂ acid gas and/or a change in temperature in the second environment relative to the first environment.

10. The method of any one of claims 1-9, wherein captured non-CO₂ acid gas forms a solid suspended in the liquid non-CO₂ acid gas sorbent and is upconcentrated by physical separation.

11. The method of claim 10, where the physical separation uses a cross-flow filter, centrifugation, crystallization, and/or sedimentation.

12. The method of claim 11, wherein the cross-flow filter is operated at a temperature of at least 200 ºC.

13. The method of any one of claims 1-12, wherein at least a portion of the non-CO₂ acid gas sorbent containing at least the portion of the non-CO₂ acid gas is removed from the environment.

14. The method of any one of claims 1-13, further comprising adding a solution to the environment to precipitate at least a portion of the non-CO₂ acid gas sorbent.

15. The method of claim 14, wherein the solution contains calcium ions.

16. The method of any one of claims 14-15, wherein adding the solution results in the precipitation of CaSO₄.

17. A method, comprising: regenerating a sorbent that has been exposed to an acid gas via exposure to steam such that at least part of the acid gas is separated from the sorbent.

18. The method of claim 17, wherein the sorbent comprises an alkali metal borate, A_xB_1-xO_1.5-x, wherein A is one or more alkali metals, B is Boron, O is Oxygen, and x is a number such that 0 < x < 1.

19. The method of claim 18, wherein the alkali metal comprises lithium (Li), sodium (Na), potassium (K), and/or a mixture of these.

20. The method of claim 19, wherein the alkali metal comprises Li and Na in equal amounts.

21. The method of any one of claims 17-20, wherein the sorbent is in molten form.

22. The method of any one of claims 17-21, wherein the acid gas comprises carbon dioxide (CO₂), sulfur dioxide (SO₂), nitrogen dioxide (NO₂), hydrogen sulfide (H₂S), sulfur trioxide (SO₃), nitric oxide (NO), and/or carbonyl sulfide (COS).

23. The method of any one of claims 17-22, wherein regenerating the sorbent comprises removing multiple acid gasses present in the sorbent.

24. The method of any one of claims 17-23, wherein at least 1 wt% of the sorbent is regenerated.

25. The method of any one of claims 17-24, wherein at least 1 mol% of the acid gas is released from the sorbent during regeneration.

26. The method of any one of claims 17-25, wherein an environment in which the sorbent was exposed to the acid gas is at the same, or similar, temperature as the environment in which the sorbent was regenerated.

27. The method of any one of claims 17-26, wherein an environment in which the sorbent is exposed to the steam is at a temperature of above 200 °C.

28. The method of any one of claims 17-27, wherein the pressure in an environment in which the sorbent is exposed to the steam is at least 1 bar.

29. The method of any one of claims 17-28, wherein the pressure in an environment in which the sorbent is exposed to the steam is at least 1.1 bar.

30. The method of any one of claims 17-29, wherein a molar ratio of steam to sorbent is at least 0.1.

31. The method of any one of claims 17-30, wherein a molar ratio of steam to acid gas in the sorbent is at least 1.

32. The method of any one of claims 17-31, wherein an environment in which the sorbent is exposed to the steam is part of an industrial process.

33. The method of any one of claims 17-32, further comprising subsequently cooling the mixture of steam and acid gas such that condensed steam is separated from the acid gas.

34. The method of any one of claims 17-33, wherein the acid gas is recovered at a purity of greater than 50 wt%.

35. The method of any one of claims 33-34, wherein the mixture is cooled in a heat exchanger to generate energy, prior to separation in the condenser.

36. The method of any one of claims 33-35, wherein the condensed steam is heated and recycled back into the regeneration environment.

37. The method of any one of claims 17-36, wherein steam quality is maintained, at least in part, by an energy source internal to a process that generates the acid gas.

38. The method of any one of claims 17-37, wherein steam quality is maintained, at least in part, by the energy content of fuel within a process that generates the acid gas.

39. The method of any one of claims 17-38, wherein steam quality is maintained, at least in part, by an energy source external to a process that generates the acid gas.

40. The method of any one of claims 17-39, wherein steam quality is maintained, at least in part, by a steam cycle powered by a process separate from a process that generates the acid gas.

41. The method of any one of claims 17-40, wherein the regenerating comprises reducing a partial pressure of the acid gas in an environment around the sorbent.

42. The method of any one of claims 17-41, wherein the steam is chemically inert with the sorbent.