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WO2024235739A1 - Procédé de production d'un écoulement fluidique désacidifié, appareil de désacidification d'un écoulement fluidique et utilisation de pompes à chaleur pour désacidifier un écoulement fluidique - Google Patents

Procédé de production d'un écoulement fluidique désacidifié, appareil de désacidification d'un écoulement fluidique et utilisation de pompes à chaleur pour désacidifier un écoulement fluidique Download PDF

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Publication number
WO2024235739A1
WO2024235739A1 PCT/EP2024/062549 EP2024062549W WO2024235739A1 WO 2024235739 A1 WO2024235739 A1 WO 2024235739A1 EP 2024062549 W EP2024062549 W EP 2024062549W WO 2024235739 A1 WO2024235739 A1 WO 2024235739A1
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stream
heat
heat transfer
thermal energy
transfer medium
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English (en)
Inventor
Johannes Felix Haus
Alexander Schroeder
Lukas Mayr
Georg Sieder
Martin RHEINFURTH
Iven Clausen
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BASF SE
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BASF SE
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Priority to CN202480032616.9A priority Critical patent/CN121127299A/zh
Priority to AU2024271426A priority patent/AU2024271426A1/en
Publication of WO2024235739A1 publication Critical patent/WO2024235739A1/fr
Anticipated expiration legal-status Critical
Pending legal-status Critical Current

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    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
    • B01D53/1425—Regeneration of liquid absorbents
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D51/00—Auxiliary pretreatment of gases or vapours to be cleaned
    • B01D51/10—Conditioning the gas to be cleaned
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
    • B01D53/18—Absorbing units; Liquid distributors therefor
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2258/00—Sources of waste gases
    • B01D2258/02—Other waste gases
    • B01D2258/0283—Flue gases
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2259/00—Type of treatment
    • B01D2259/65—Employing advanced heat integration, e.g. Pinch technology

Definitions

  • This invention relates to a method for producing a deacidified fluid stream comprising serially connected heat pumps to transfer energy from a heat source to the regeneration step.
  • the invention in a second aspect, relates to an apparatus for producing a deacidified fluid stream comprising serially connected heat pumps.
  • the invention relates to the use of a two serially connected heat pumps for transferring thermal energy from a heat source to the regeneration step in a process for deacidifying a fluid stream.
  • Carbon dioxide is one of the most abundant greenhouses gases in the atmosphere. Greenhouse gases are such gases that absorb and emit infrared radiation in the wavelength range emitted by the earth and thus contributing to global warming. CO2 levels in the atmosphere have increased from approx. 280 ppm in preindustrial times at around the year 1750 to about 421 ppm in the year 2022. Approximately two thirds of all carbon dioxide emissions result from the combustion of fossil fuels.
  • Carbon capture and storage (CCS) or carbon capture utilization and storage (CCUS) are readily available and developed technologies which can be implemented on a large scale and on a shorter timescale and can therefore have a more immediate impact on climate change.
  • Carbon dioxide may be captured directly from industrial sources, such as cement production, natural gas processing and ammonia and hydrogen production, or from fossil or biomass fuel powered power plants.
  • a carbon capture rate from flue gas from carbon-based fuels of 80 to 95% is currently feasible.
  • Captured carbon dioxide can be removed from the atmosphere by carbon sequestration or carbon storage in suited geological formations, such as depleted oil and gas reservoirs, mines and saline or other rock formations. Prior to transporting carbon dioxide to its final storage place and injection to the underground, it is usually compressed to high pressures of around 100 bar. Other utilizations of captured carbon dioxide are enhanced oil recovery or conversion to fuel, cement, minerals, or chemicals.
  • Amine gas treating is one of most mature methods for carbon capture.
  • Amine gas treating refers to processes in which acidic gases (sour gas), such as carbon dioxide or hydrogen sulfide are removed from a feed gas stream by absorption in amine solvents.
  • a typical acid gas removal unit comprises an absorber and a regenerator as well an ancillary equipment.
  • the absorber the downflowing amine absorbs the acidic components of the feed gas to obtain a sweetened gas or sweet gas stream and an amine solution partially laden with the acidic components ("rich amine”).
  • the rich amine solution is then fed to a regenerator or stripper where it is heated to strip or flash the desorbed acid gas overhead and to produce a regenerated amine solutions ("lean amine”) which can be recycled to the absorber. Stripped CO 2 is then compressed, dried, and optionally refrigerated and transported to its storage destination.
  • Amine gas treating is a relatively energy intensive process. It has been estimated that up to 40 percent of the energy produced by a power station is consumed by carbon capture and sequestration. This energy penalty splits into a value of around 60% for the amine gas treating process and 30% for carbon dioxide compression.
  • the energy extensive part of amine gas treating is the stripping of captured carbon dioxide in the stripper. Temperatures in the absorber are usually around 30 to 70°C, whereas the temperatures necessary to strip carbon dioxide are usually in the range of 100 to 150°C.
  • the energy required for heating the rich amine is usually supplied by transferring heat from hot process steam to the rich amine in the regenerator.
  • Process steam may be produced in combined cycle gas power plants. In such cases, steam production from power production may be integrated into the amine gas treating process.
  • a steam integration with existing steam sources is not always possible for all AGRUs and the required steam then needs to be provided by a stand-alone process steam production process, such as a steam boiler.
  • numerous activities address the need to reduce the energy consumption of amine gas treating units.
  • One possible strategy to reduce the energy consumption is by trying to improve the cyclic capacity of the amine solvent and reduce the energy required to regenerate the amine solvent.
  • Solvent development is however quite cost and time extensive and often requires the use of specialized, high priced solvent systems leading to higher operational costs.
  • Another strategy employed to reduce the energy consumption of amine gas treating units is to transfer heat from sources within the gas treating unit having a higher temperature to places having a lower temperature.
  • US3101996 also teaches the utilization of hot fluid streams, such as synthesis gas or hydrogen gas obtained in a water shift reaction, to produce steam in separates boilers which can be used to heat the amine stripper.
  • W0200712143 discloses two separate cooling stages for cooling hot flue gas from a steam turbine before amine gas treating. In an initial stage, the flue gas is cooled in a heat exchanger by indirect heat exchange with a fluid that is used to heat the stripper. In a second stage, the flue gas is cooled by transferring thermal energy to a heat pump system used to heat the stripper. The heat pump system can be supplemented by heat regenerated in other heat sources, such as the CO2-compression stage.
  • heat pumps to transfer energy from process units of a higher thermal energy level to process units having a lower thermal energy level is not only limited to the hot feed gases.
  • Many heat source in an amine gas treating process has been suggested for utilization with a heat pump.
  • WO2010097047 and WO2011122525 utilize the heat of absorption in the absorber as a heat source for heat pumps to heat the rich amine solution.
  • JP2015131735 uses an intercooler loop in the absorber as a heat source for a heat pump to heat the stripper.
  • W0200781214 and CN114405258 discloses the use of the condensation energy generated in the condenser of a stripper as a heat source.
  • WO201258558 describes the use of the thermal energy of the stripper gas in the overhead condenser as heat source for a heat pump.
  • the disclosure is limited to the removal of SO2 from gaseous mixtures, but the principle can theoretically be transferred to CO2-removal.
  • JP2010088982 discloses the use of the heat of compression generated in the compressor(s) used to compress the carbon dioxide to high pressures to heat the rich amine solution.
  • JP2015131736 essentially teaches the replacement of the conventional crossflow heat exchanger used to transfer heat from the hot lean amine solution exiting the stripper to the rich amine solution entering the stripper with a heat pump.
  • FR2968574 discloses the use of multiple heat sources for heat pumps, such as the overhead condenser of the stripper, the lean amine solution exiting the absorber and the overhead condenser of the absorber used to remove water vapor from the sweetened gas.
  • CN 10289584 mentions the use of the lean amine solution exiting the regenerator stripper and the stripper overhead condenser as a heat source for heat pumps.
  • CN112126477 discloses the use of blast furnace slag rinsing water as a heat source for heating the stripper with a heat pump.
  • the energy comprised in the disclosed various heat sources is usually not high enough to provide the full energy required in the stripping step. Therefore, multiple heat sources need to be tapped requiring the use of more than one heat pump. The use of several heat pumps increases the capital costs of an amine gas treating unit.
  • US2013056676 related to a polarity swing-assisted regeneration (PSAR) method for improving the efficiency of releasing gases chemically bound to switchable ionic liquids (SWIL).
  • PSAR polarity swing-assisted regeneration
  • SWIL switchable ionic liquids
  • Regeneration of the SWIL involves addition of a quantity of non-polar organic compound as an anti-solvent to destabilize the SWIL, which aids in release of the chemically bound gas.
  • the PSAR decreases gas loading of a SWIL at a given temperature and increases the rate of gas release compared to heating in the absence of anti-solvent.
  • regeneration includes transferring heat with a heat pump to one or more of: a condenser, an evaporator, an absorber, a cooler, a separator, a regenerator, or a reboiler.
  • WO2023/057372 relates to a gas capture system in which gas is captured by a liquid sorbent.
  • the sorbent is re-cir- culated between a first reactor system and a second reactor system.
  • the sorbent captures a gas in a gas stream in an exothermic process.
  • the sorbent is regenerated and the captured gas is released in an endothermic process.
  • the second gas capture system may be operated at a lower pressure than the first gas capture system. It is further disclosed that a number of different configurations of heat pump integration may also be used within the gas capture system as an efficient means for electrification of the system.
  • the problem underlying the present invention was to provide a way for reducing the energy demand of a gas treating unit using a liquid absorbent while reasonably limiting additional investments into the plant infrastructure.
  • a further problem underlying the present invention was to reduce corrosion and fouling in equipment being in contact with the fluid stream.
  • Another problem underlying the present invention was to avoid the need for costly equipment required to transport gaseous streams.
  • it was an object of the present invention to electrify steam production required for the regeneration of a rich absorbent solution and to potentially detach steam production from power production in the power plant or the need to provide stand-alone steam producing facilities.
  • a further object of the present invention was to reduce the energy demand for steam production required in the regeneration step.
  • Still another object of the present invention was to provide for a flexible process which allows for fluctuations of capacity of the AGRU.
  • the invention is directed to a method for producing a deacidified fluid stream comprising at least one acid gas, comprising: a) a thermal energy transfer step in which thermal energy is transferred from a heat stream HS1 to the regeneration step c) to obtain a heat stream HS2 having a reduced thermal energy compared to heat stream HS1; b) an absorption step in which a fluid stream FS2 is contacted with an absorbent A1 in an absorber to obtain an absorbent A2 laden with acid gases and an at least partly deacidified fluid stream; c) a regeneration step in which at least a portion of the laden absorbent A2 obtained from step b) is regenerated in a regenerator obtain an at least partly regenerated absorbent A3 and a gaseous stream GS comprising least one acid gas; d) a recycling step in which at least a substream of the regenerated absorbent A3 from step c) is recycled into the absorption step b); wherein the thermal energy transfer step a
  • the method of the present invention comprises transferring thermal energy from a heat stream HS1 to the regeneration step c) to obtain a heat stream HS2 having a reduced thermal energy compared to stream HS1.
  • Heat stream HS1 preferably generates from a heat source HS.
  • the heat source HS can be any heat source from a gas treatment process or an external heat source outside the gas treatment process.
  • a heat source HS may be the heat of absorption occurring in the absorber, which can be utilized in an intercooler or by the integration of heat exchangers into the absorber.
  • the stream HS1 is a hot stream exiting the absorber and the stream HS2 is a cooled stream entering the absorber.
  • Another heat source HS is the heat of absorption in the rescrubbing zone at the top of the absorber, if the rescrubbing zone is equipped with a pump and a cooler.
  • the stream HS1 is a hot stream exiting the rescrubbing zone of the regenerator and the stream HS2 is a cooled stream entering the regenerator.
  • Still another heat source HS is the heat of condensation of condensate at the head of the absorber or the regenerator.
  • the stream HS1 is a warm cooling medium stream exiting a condenser or a backwash zone with a cooled pump around at the head of the absorber or the regenerator and the stream HS2 is a cooled cooling medium stream entering this device.
  • Another heat source HS is the heat of compression in the compression step which is created when compressing gaseous stream GS as further described below.
  • stream HS1 is compressed stream GS and stream HS2 is a cooled compressed stream GS.
  • stream HS1 is a fluid stream FS1 .
  • the fluid stream FS1 from which thermal energy is transferred to the regeneration step c) may be any fluid stream comprising at least one acid gas.
  • the fluid stream FS1 comprises CO2.
  • CO2 other acid gases, such as H2S, CS2 or COS may be present.
  • oxides of sulfur and nitrogen SO x and NO X may also be present.
  • the content of acid gases in the fluid stream FS1 is generally 0.01% to 40% by volume, preferably 2% to 30% by volume and more preferably 3% to 25% by volume.
  • the fluid stream FS1 introduced into the process of the invention may comprise water.
  • the water content in the fluid stream is generally within a range from > 0% by volume up to a content corresponding to the saturation concentration of water in the fluid stream under the existing pressure and temperature conditions.
  • the temperature of fluid stream FS1 is preferably in the range from 40 to 300°C, preferably 50 to 250°C and most preferably 60 to 200°C.
  • the method according to the present invention is particularly suited for flue gases having a low temperature in the range of 60 to 250°C as the thermal energy comprised in such low temperature fluid gas streams FS1 can be transferred to the energy levels required in the regeneration step c) by the combination of two or more heat pumps in series.
  • the pressure of fluid stream FS1 usually depends on the source of the fluid stream FS1 as further outline below.
  • the fluid stream 1 is a flue gas.
  • Flue gases are preferably obtained by combustion of carbon-based fuels, such as fossil fuels like coal, natural gas and oil, or biomass feedstocks from plants, algae or animals.
  • carbon-based fuels such as fossil fuels like coal, natural gas and oil, or biomass feedstocks from plants, algae or animals.
  • the source of the flue gas is from combustion of coal, natural gas, oil, biofuels, such as bioethanol or biodiesel, or biomass derived from forestry, agriculture or aquaculture.
  • fluid stream FS1 is a flue gas exiting the steam turbine of a steam-electric power stations in which the generator is driven by steam obtained from the combustion of carbon-based fuels.
  • fluid stream FS1 is a flue gas exiting the steam turbine of a gas-fired power plant which is designed as a simple cycle gas-turbine or a combined cycle power plant.
  • the flue gas stream FS1 Prior to being used in the method of the present invention, the flue gas stream FS1 is optionally treated to remove particulate matter by filtration or electrostatic precipitation.
  • the flue gas stream FS1 is desulfurized by removing sulfur dioxide.
  • fluegas desulfurization https://en.wikipe- dia.org/wiki/Flue-gas desulfurization.
  • Fluid flue gas stream FS1 preferably comprises:
  • CO2 1 to 25 vol.%, preferably 5 to 20 vol.-%;
  • H2O 3 to 50 vol.%, preferably 5 to 30 vol.-%;
  • flue gases comprise small amounts of other gases, in particularly nitrogen oxides (NO X ) and sulfur oxides (SO X ), even after a flue gas desulfurization step.
  • Flue gas also comprises nitrogen in an amount so that sum of the volume fractions of each component present in the flue gas add up to a value of 1 (or 100 vol.-%).
  • the nitrogen content is in the range of 40 to 95 vol.%.
  • Fluid stream FS1 is preferably in the gaseous state. Depending on the temperature and the water content, fluid stream FS1 may also comprise condensed water and acids.
  • the pressure of the fluid stream FS1 entering the cooling step is usually at atmospheric pressure, preferably in the range of 0.7 to 1.5 bar, more preferably 0.8 to 1.3 bar and more preferably 0.9 to 1.2 bar.
  • the temperature of fluid flue gas stream FS 1 is preferably in the range of 50 to 300°C, preferably 60 to 250°C and most preferably 60 to 200°C.
  • Fluid stream FS1 may also be an off-gas stream in which CO2 is emitted in an industrial process which liberates CO2 from a chemical reaction.
  • industrial process streams include CO2-emissions from the thermal decomposition of limestone and dolomite in the production of cement, CO 2 -emissions from using carbon as a reducing agent in the commercial production of metals from ores (e.g. the production of iron in a blast furnace), or CO2-emissions from the fermentation of biomass (e.g. to convert sugar to alcohol).
  • fluid stream FS1 is stream which combines flue gas from a carbon-fuel combustion process with CO2-emissions from a CC producing industrial process, such as cement production, metal production or fermentation processes.
  • fluid stream FS1 is a flue gas stream coming from a furnace of a cracker, in which hydrocarbons, such as petroleum fractions, naphtha, natural gas liquids, such methane, ethane and propane, are thermically or catalytically cracked to obtain shorter chain molecules or recombined molecules having a different structure.
  • the fluid stream FS1 is the flue gas of a steam cracker furnace.
  • the fluid stream FS1 may alternative be a crude synthesis gas.
  • a synthesis gas (or "syngas”) may be obtained from the gasification of coal or mineral oil, steam reforming of mineral oil distillates, the steam reforming of methane, or auto thermal reforming of natural gas. Syngas usually comprises hydrogen, carbon monoxide and some carbon dioxide and water.
  • a preferred fluid stream FS1 is the fluid stream exiting the water shift reactor in the production of synthesis gas.
  • the water shift reaction is preferably carried out as a high temperature shift conversion (HTSC) at temperature of about 300 to 450°C, a medium temperature shift conversion (MTSC) at temperatures of about 150 to 350°C, a low temperature shift conversion (LTSC) at temperatures of about 150 to 250°C or a sour gas shift conversion (SGS) at temperatures of about 200 to 300°C.
  • HTSC high temperature shift conversion
  • MTSC medium temperature shift conversion
  • LTSC low temperature shift conversion
  • SGS sour gas shift conversion
  • the total pressure is usually in the range of 5 to 120 bar, preferably 10 to 100 bar and more preferably 10 to 60 bar.
  • the method of the present invention comprises a thermal energy transfer step a) in which thermal energy is transferred from a heat stream HS1 to the regeneration step c) to obtain a heat stream HS2 having a reduced thermal energy compared to heat stream HS1.
  • the thermal energy transfer step a) comprises at least two (or two or more) heat pumps which are connected in series.
  • the heat pumps can be an open-loop heat pump or a closed loop heat pump.
  • the working medium or heat transfer medium is essentially contained in a closed loop, meaning that the working medium or heat transfer medium is essentially in a steady-state and not in contact with an outside sink or outside sources.
  • a heat pump with an open loop, the working medium or heat transfer medium is essentially not in a closed loop.
  • a heat pump is a device for transferring heat from a heat source at one temperature to a heat sink at a higher temperature.
  • An open-loop heat pump usually comprises the steps of: transferring thermal energy from the heat source to a heat transfer material, usually by means of a heat exchanger, which usually is designed as an evaporator for at least a part of the heat transfer material of the heat pump. compressing partially gasified heat transfer material in one or more compression steps, which usually include one or more compressors, to increase the temperature of the heat transfer material, and transferring thermal energy from the compressed heat transfer material to the heat sink, usually by means of another heat exchanger functioning as a condenser for the at least partially gaseous heat transfer material of the heat pump.
  • An open loop heat pump has the advantage that it can utilize media from a variety of sources, in particularly water which is usually already present in an amine gas treating process.
  • a closed-loop heat pump usually comprises a heat transfer medium between the heat source and the heat sink in a closed loop. This is usually implemented by additional recycling steps for the heat transfer medium, such as the recycling steps R1 or R2 for heat pumps HP1 or HP2 which are further described below.
  • the requirement of using two heat pumps which are connected in series means that the compressed heat transfer medium of heat pump HP1 serves as a heat source for the heat medium transfer stream of heat pump HP2, which acts as the heat sink for heat pump HP1 and that thermal energy from heat transfer medium stream HTMS of heat pump HP1 to the heat transfer medium stream of heat pump HP2 is being affected through a common heat exchanger HE2.
  • the heat exchanger HE2 functions as a condenser for the heat transfer material of heat pump HP1 as well as an evaporator for the heat transfer material of heat pump HP2.
  • the use of two heat pumps which are connected in series has the advantage that the thermal energy from the heat stream HS1 can be raised to a level at where it is possible to generate steam in heat pump HP2 which can be used to transfer heat to the regeneration step c).
  • the stream produced in heat pump HP2 can therefore effectively replace process steam usually required as a heat source in the regeneration step c).
  • the use of two heat pumps in series can replace the requirement to have a separate process steam production process installed at the site of the acid gas removal unit or the requirement for steam turbines, such as back pressure turbines or pass-out condensing turbines, to produce process steam at the electric power plant which is to be decarbonized.
  • the present invention is therefore particularly useful where process steam is not readily available at the site of an acid gas removal unit.
  • the method according to the present invention may be useful as an alternative method to produce process steam as it allows to use potentially limited process steam resources for other uses or allows to reduce power loss of power plants associated with process steam production.
  • the method of the present invention is an interesting alternative in the design of new power plants coupled to an acid gas removal unit for carbon capture because the requirement to divert energy for steam production to power the recycling step can be reduced.
  • the method of the present invention is a useful method to electrify steam production so that the steam required in the amine gas treating process can be provided by "green” electricity from renewable resources.
  • At least one, but preferably both, of the heat pumps comprises the step of expansion of the compressed heat transfer medium stream after transfer of thermal energy to the heat sink.
  • These recycling steps R1 or R2 allow the recycle of heat transfer material to the transfer step a) leading to a further efficiency increase of the method, as the need to replenish heat transfer material is significantly reduced. This method is especially advantageous when using heat transfer materials which have a detrimental impact on the environment, in which case it is advisable to contain these materials in a closed cycle.
  • At least one, preferably the last of the serially connected heat pumps is operated as an open-loop heat pump, especially if the heat transfer material HTM used in the last heat pump is water.
  • HTM heat transfer material
  • Heat transfer from the heat stream HS1 to the heat transfer material stream HTMS1 of the first heat pump HP1 may occur directly by exchanging thermal energy from heat stream HS1 to heat transfer material stream HTMS1 in a heat exchanger HE1.
  • heat transfer from heat stream HS1 to the heat transfer material stream HTMS1 of the first heat pump HP1 may occur indirectly via an intermediate cooling step.
  • thermal energy from heat stream HS1 is transferred to a cooling medium stream CMS1 to obtain a cooled heat stream HS2 and a cooling medium stream CMS2 having an increased thermal energy compared to cooling medium stream CMS1.
  • Thermal energy is then further transferred from cooling medium stream CMS2 to the heat transfer material stream HTMS1 of the first heat pump HP1 .
  • the heat transfer from the cooling step is usually affected by an additional heat exchanger HE-C, which is preferably a gas-to-liquid heat exchanger when heat stream HS1 is a fluid stream FS1.
  • the transfer of heat via an additional cooling step allows for the possibility of the direct transfer thermal energy to the cooling medium stream CMS1 , preferably using a direct contact cooler (DCC) as a heat exchanger.
  • DCC direct contact cooler
  • Direct contact means that the streams are not separated by a portioning but are in direct physical contact with each other (direct heat exchange).
  • Direct heat exchange is opposed to indirect heat transfer, where the heat stream HS1 and the cooling medium stream CMS1 are not in direct contact and heat exchange takes place indirectly through a separating wall or into and out of a wall in a transient manner (indirect heat exchange).
  • Direct heat exchange has the advantage that the exchange area between the two streams HS1 and CMS1 increases, which reduces thermal resistances and maximizes the thermal efficiency.
  • direct heat exchangers usually have lower operating and capital costs than indirect heat exchangers due to a high heat transfer rate per volume and because fouling and corrosion is usually not a problem.
  • the heat transfer step a) of the present invention occurs directly from heat stream HS1 and the heat transfer material HTM1 of heat pump 1 and preferably comprises the steps of:
  • step 1) of the method according to the present invention proceeds indirectly via an intermediate cooling step and comprises the steps of:
  • the method of the present invention also comprises one of both of the following recycling steps:
  • step 1) of the preferred embodiment of the present invention thermal energy is transferred from heat stream HS1 to a heat transfer medium stream HTMS1 of the first heat pump HP1 to obtain a heat transfer medium stream HTMS2 having an increased thermal energy compared to heat transfer medium stream HTMS1. Further a cooled heat stream HS2 is obtained having a lower thermal energy compared to heat stream HS1.
  • heat pump HP1 is a device suitable for transferring thermal energy from the heat stream HS1 as the heat source to a heat transfer medium stream HTMS1 of heat pump HP1.
  • heat pump HP1 may be an open loop heat pump or a closed loop heat pump.
  • Heat pump HP1 preferably comprises: a heat exchanger HE1 for the transfer of thermal energy from heat stream HS1 to the heat transfer medium stream HTMS1 of heat pump HP to obtain a heat transfer material stream HTMS2 having an increased thermal energy compared to heat transfer medium stream HTMS1 ,
  • - one or more compressors for compressing heat transfer material stream HTMS2 in one or more compression steps to obtain a heat transfer material stream HTMS3 having an increased pressure compared to heat transfer material stream HTMS2, a heat exchanger HE2 for the transfer of thermal energy from heat transfer material stream HTMS3 of the first heat pump to a second heat transfer material stream SHTMS1 of the second heat pump HP2 to obtain a heat transfer material stream HTMS4 of the first heat pump HP1 having a reduced thermal energy compared to heat transfer material stream HTMS3, and
  • HP1 if HP1 is a closed loop heat pump, HP1 preferably comprises:
  • the heat transfer material HTM1 is a working fluid used in heat pump HP1 to transport thermal energy from heat exchanger HE1 to heat exchanger HE2.
  • the heat transfer material HTM1 can undergo at least a partial phase transition from the liquid to the gas state upon transfer of thermal energy in heat exchanger HE1 .
  • the heat transfer material HTM1 can also undergo at least a partial phase transition from the gas to the liquid state upon transfer of thermal energy in heat exchanger HE2 to the second heat pump HP2.
  • Heat transfer material HTM1 is therefore preferably selected from the group of refrigerants consisting of ammonia, butane, R1233zd(e), R1224yd(z), air, CO2, water, chlorofluorocarbon, hydrochlorofluorocarbon, hydrofluorocarbon, hydrofluoroolefin, hydrochlorofluoroolefin, hydrocarbon, perfluoro(2-methyl-3-pentanone) and mixtures of two or more thereof.
  • Suitable refrigerants are known to the skilled person and are disclosed, for example, in C. Arpagaus et al. (C. Arpagaus et al., Energy 152 (2018), pages 985 to 1010).
  • Heat transfer material streams 1 to 5 are streams of heat transfer material 1 in different stages of the heat pump HP1, wherein: heat transfer material stream HTMS1 is the stream of heat transfer material HTM1 entering step 1); heat transfer material stream HTMS2 is the stream of heat transfer material HTM1 exiting step 1) and entering compression step 2); heat transfer material stream HTMS3 is the stream of heat transfer material HTM1 exiting compression step 2) and entering step 3); heat transfer material stream HTMS4 is the stream of heat transfer material HTM1 exiting step 3) and which optionally can enter recycling step R1); heat transfer material stream HTMS5 is the stream of heat transfer material HTM1 exiting recycling step R1).
  • step 1) of the present invention 1) thermal energy from heat stream HS1 is transferred to a heat transfer medium stream HTMS1 of the first heat pump HP1 to obtain a heat transfer medium stream HTMS2 having an increased thermal energy compared to heat transfer medium stream HTMS1. And a cooled heat stream HS2 having a lower thermal energy compared to heat stream HS1 .
  • the thermal energy of heat stream HS1 is directly transferred to heat transfer material stream HTMS1 of heat pump HP1.
  • the transfer of thermal energy from heat stream HS1 to the heat transfer material stream HTMS1 is usually affected by a heat exchanger HE1 .
  • the exchanger HE1 usually is a device that is used to transfer thermal energy in the form of heat between heat stream HS1 and heat transfer medium stream HTMS1 to obtain heat transfer medium stream HTMS2 having an increased thermal energy compared to heat transfer medium HTMS1 and a heat stream HS2 having a reduced thermal energy compared to heat stream HS1.
  • the heat exchanger HE1 is an indirect heat exchanger in which the transfer of heat between heat stream HS1 and heat transfer medium stream HTMS1 takes indirectly through a separating wall or into and out of a wall in a transient manner without any physical contact or material transfer between the two streams (indirect heat exchange).
  • HE1 When heat exchanger HE1 is an indirect heat exchanger, HE1 usually comprises: an inlet of heat stream HS1 having a pressure PHSI and the temperature T HSI at the entrance of the inlet; an outlet for heat stream HS2 having a pressure PHS2 and a temperature THS2 at the exit of the outlet; an inlet for a heat transfer medium stream HTMS1 having a pressure PHTMSI and the temperature THTMSI at the entrance of the inlet; and an outlet for heat stream HS2 having a pressure PHTMS2 and a temperature T HTMS2 at the exit of the outlet.
  • heat exchanger HE1 is an indirect gas-to-liquid heat exchanger in which heat is transferred between the gaseous heat stream HS1 to the liquid heat transfer material stream HTMS1.
  • the gas-to-liquid heat exchanger is an extended surface heat exchanger as described in Chapter 2.1.3 of the Article "Heat Exchangers, 1. Fundamentals and General Design Methodology” in Ullmann's Encyclopedia of Industrial Chemistry, https://doi.org/10.1002/14356007.b03 O2.pub2, more preferably a plate-fin heat exchanger, such as the ones described in Chapter 2.1 .3.1 of the same reference, or a tube-fin-heat exchanger, such as described in Chapter 2.1 .3.2 of the same reference.
  • the heat exchanger HE1 is preferably designed in a manner so that following requirement are fulfilled: the temperature THTMSI is preferably 1 to 100 K, more preferably 2 to 60 K and most preferably 5 to 30 K lower than TFSI. the temperature TFS2 is preferably in the range of 20 to 80°C, more preferably 25 to 70°C and most preferably in the range of 30 to 60°C. the heat transfer material stream HTMS1 undergoes at least a partial phase transition from the liquid to the gaseous state in heat exchanger HE1 .
  • a pressure drop occurs in an indirect gas-to-liquid heat exchanger.
  • a gaseous heat stream HS2 such as FS2
  • heat exchanger HE1 to the absorber and to overcome the pressure drop in the indirect heat exchanger HE1
  • an additional blower or fan is recommended after the outlet of heat stream HS2.
  • heat exchanger HE1 is designed in a manner that more energy is transferred than is needed in the regeneration step.
  • the excess energy can be preferably used to provide excess steam which can be transferred to an onsite steam network to be distributed to other processes or process steps on site, which may require such energy.
  • heat exchanger HE1 in a manner that less energy is transferred than is needed in the regeneration step.
  • it is preferably to provide additional energy, preferably steam, to the regeneration step from other sources, e.g., an onsite steam network which distributes steam from other steam producing sources.
  • heat exchanger HE1 is preferably designed in a manner that the transferred thermal energy is just sufficient to provide the thermal energy required in the regeneration step c). If more thermal energy or heat is comprised in heat stream FS1 than is necessary to be transported by the heat pumps to the regeneration step c), than only the energy required in the regeneration step c) is transferred in heat exchanger HE1 .
  • fluid stream FS2 would be too hot to enter the absorber, it is preferable that the fluid stream FS2 exiting heat exchanger HE1 is cooled in one or more additional heat exchangers prior to entering the absorber, so that fluid stream FS2 has a temperature in the range of 20 to 80°C, more preferably 25 to 70°C and most preferably 30 to 60°C at the inlet of the absorber.
  • Such additional heat exchanger are classical heat exchangers, such as plate heat exchangers, shell and tube heat exchangers, air coolers or water coolers, such as cooling towers.
  • An overview over cooling towers which can be used to further cool fluid stream FS2 can be found in the Wikipedia article "Cooling towers” (https://en.wikipe- dia.org/wiki/Cooling tower#).
  • This embodiment has the advantage that the temperature of fluid stream FS2 at the absorber inlet can be independently adjusted from the operation of the heat pump HP1 .
  • the heat transfer step 1) of transferring thermal energy from heat stream HS1 to a heat transfer medium stream HTMS1 of the first heat pump HP1 to obtain a heat transfer medium stream HTMS2 having an increased thermal energy compared to heat transfer medium stream HTMS1 comprises the steps of: la) transferring thermal energy from heat stream HS1 to a cooling medium stream CMS1 to obtain a) a heat stream HS2 having a decreased thermal energy content compared to heat stream HS1, and b) a cooling medium stream CMS2 having an increased thermal energy content compared to CMS1; lb) transferring at least a part of the thermal energy comprised in cooling medium CMS2 to a heat transfer medium stream HTMS1, thereby obtaining a heat transfer medium stream HTMS2, which has an increased thermal energy compared to HTMS1, and a cooling medium stream CMS3, which has a reduced thermal energy compared to CMS2 and which is at least partially recycled to step 1a) as CMS1.
  • Step 1a) Transfer of Thermal Energy via Heat Exchanger HE-C
  • the transfer of thermal energy from heat stream HS1 to the cooling medium stream CMS1 in step 1a) is preferably affected in a heat exchanger HE-C.
  • Heat exchanger HE-C preferably comprises: an inlet for heat stream HS1 having a pressure PHSI and the temperature THSI at the entrance of the inlet; an outlet for heat stream HS2 having a pressure PHS2 and a temperature THS2 at the exit of the outlet; an inlet for a cooling medium stream CMS1 at a pressure PCMSI and the temperature TCMSI at the entrance of the inlet; and an outlet for cooling medium stream CMS2 having a pressure PCMS2 and a temperature TCMS2 at the exit of the outlet
  • heat exchanger HE-C is aa indirect gas-to-liquid heat exchanger in which heat is transferred between the gaseous stream HS1 to the liquid cooling medium stream CMS1.
  • the gas-to-liquid heat exchanger is an extended surface heat exchanger as described in Chapter 2.1.3 of the Article "Heat Exchangers, 1.
  • a plate-fin heat exchanger such as the ones described in Chapter 2.1.3.1 of the same reference, or a tube-fin-heat exchanger, such as described in Chapter 2.1.3.2 of the same reference.
  • the heat exchanger HE-C is preferably designed in a manner so that following requirement are fulfilled: the temperature TCMSI is preferably 1 to 100 K, more preferably 2 to 80 K and most preferably 5 to 50 K lower than TFSI. the temperature THS2 is preferably in the range of 20 to 80°C, more preferably 25 to 70°C and most preferably in the range of 30 to 60°C.
  • heat exchanger HE-C is preferably a direct heat exchanger, where the heat stream HS1 is in direct contact with the cooling medium stream CMS1 .
  • Direct contact means that the streams are not separated by a partitioning but are in direct physical contact with each other (direct heat exchange).
  • Direct heat exchange has the advantage that the exchange area between the two fluid streams HS1 and CMS1 increases, which reduces thermal resistances and maximizes the thermal efficiency.
  • direct heat exchangers usually have lower operating and capital costs than indirect heat exchangers due to a high heat transfer rate per volume and because fouling and corrosion is usually not a problem.
  • Corrosion is a non-negligible problem in indirect heat exchangers in case of residual sulfur oxides (SOx) in the fluid stream FS1 which can cause dew point corrosion if the temperature of any metal in contact with FS1 is below the dew point of sulfuric acid, which typically is in the range of 110 to 170°C.
  • SOx residual sulfur oxides
  • the pressure loss in a direct heat exchanger HE-C is lower compared to an indirect gas-to-liquid heat exchanger. Therefore, the size of costly equipment, such as fans or blowers, required to compensate the pressure loss and to transport fluid stream FS2 to the absorber can be reduced or even avoided.
  • Direct contact preferably occurs in a direct contact cooler (DCC) in which heat is transferred from fluid stream FS1 to the liquid cooling medium stream CMS1.
  • DCC direct contact cooler
  • Direct contact cooling can be accomplished with the following devices: a) spray columns, b) baffle tray columns, c) sieve tray or bubble tray columns, d) packed columns, e) pipeline contactors, and f) mechanically agitated contactors.
  • direct contact coolers are operated in a counter flow mode, meaning that the heat stream HS1 typically enters at an inlet opposite the inlet for the cooling medium stream CMS1 .
  • DCC parallel flow mode, where CMS1 and HS1 enter the heat exchanger from the same direction.
  • a parallel flow mode DCC is described in US9034081.
  • Most preferred direct contact coolers are spray columns, baffle tray columns, sieve tray or bubble tray columns and packed columns. More preferably the coolers are operated in a counter current flow mode.
  • heat stream HS1 comes into direct contact with cooling medium stream CMS1 and thermal energy is transferred from heat stream HS1 to obtain a cooled heat stream HS2 and a heated cooling medium stream CMS2.
  • the cooling medium stream CMS1 is preferably ethylene glycol, 1 ,2-propylene glycol, 1 ,3-propyleneglycol and their corresponding polyglycols, such as diethylene glycol, triethylene glycol, 1 ,2-dipropylene glycol, 1, 2 tripropylene glycol, 1 ,3-dipropylene glycol and 1, 3 tripropylene glycol, their corresponding methyl or dimethyl ether, water and mixtures thereof.
  • the cooling medium stream is ethylene glycol or water, or mixtures of ethylene glycol and water Most preferably the cooling medium stream essentially consists of water.
  • the use of pure water has the advantage that an additional separation step is not needed.
  • An additional separation step is preferred when the cooling medium stream CMS1 comprises other components than water because the water which is comprised in the heat stream HS1 leads to a dilution of the concentration of the other, non-aqueous components. To restore the original concentration, an additional separation step would be needed to separate the water introduced with heat stream HS1.
  • the direct contact cooler is preferably designed in a manner so that following requirement are fulfilled: the temperature TCMSI is in the range of 25 to 100, preferably 25 to 70 and more preferably 30 to 50°C.
  • the temperature TCMS2 is approximately 5 to 100 K preferably 10 to 80 K and more preferably 15 to 50 K higher than TCMSI
  • the temperature T H s2 is preferably in the range of 20 to 80°C, more preferably 25 to 70°C and most preferably in the range of 30 to 60°C.
  • the DCC is usually also operated so that cooling medium stream CMS2 remains in a liquid state so that it can therefore be readily separated from gaseous fluid stream FS2.
  • a part of the cooling medium stream CMS2 may be purged from the cooling medium stream cycle if additional moisture comprised in heat stream HS1 , in particularly if HS1 is fluid stream FS1 , is condensed in the DCC.
  • the amount of cooling medium stream purged is selected in a manner that the cooling medium flow rate remains essentially constant.
  • heat exchanger HE-C is designed in a manner that more energy is transferred than is needed to provide to the regeneration step.
  • the excess energy can be preferably used to provide excess steam which can be transferred to an onsite steam network to be distributed to other processes or process steps on site, which may require such energy.
  • heat exchanger HE-C in a manner that less energy is transferred than is needed in the regeneration step.
  • it is preferably to provide additional energy, preferably steam, to the regeneration step from other sources, e.g an onsite steam network which distributes steam from other steam producing sources.
  • heat exchanger HE-C is preferably designed in a manner that the transferred thermal energy is just sufficient to provide the thermal energy required in the regeneration step c). If more thermal energy or heat is comprised in heat stream FS1 than is necessary to be transported by the heat pumps to the regeneration step c), than only the energy required in the regeneration step c) is transferred in heat exchanger HE-C.
  • fluid stream FS2 If after transfer of the heat or thermal energy required for the regeneration step c), fluid stream FS2 would be too hot to enter the absorber, it is preferable that the fluid stream FS2 exiting heat exchanger HE-C is cooled in one or more additional heat exchangers prior to entering the absorber, so that fluid stream FS2 has a temperature in the range of 20 to 80°C, more preferably 25 to 70°C and most preferably 30 to 60°C at the inlet of the absorber.
  • additional heat exchanger are air coolers or water coolers, such as cooling towers.
  • An overview over cooling towers which can be used to further cool fluid stream FS2 can be found in the Wikipedia article "Cooling towers” (https://en.wikipe- dia.org/wiki/Cooling tower#).
  • This embodiment has the advantage that the temperature of fluid stream FS2 at the absorber inlet can be independently adjusted from the operation of the heat pump HP1 .
  • step 1b) is preferably carried out by transferring at least a part of the thermal energy comprised in cooling medium CMS2 to a heat transfer medium stream HTMS1 of heat pump HP1, thereby obtaining a heat trans-fer medium stream HTMS2, which has an increased thermal energy compared to HTMS1 , and a cooling medium stream CMS3, which has a reduced thermal energy compared to CMS2 and which is at least partially recycled to step 1 a) as CMS1.
  • step 1 b) CMS2 functions as a heat source for heat pump HP1 and thermal energy is transferred from cooling medium stream CMS2 to heat transfer medium stream HTMS1 .
  • the transfer of thermal energy in step 1 b) is preferably affected by a heat exchanger HE1 which is preferably an indirect heat exchanger.
  • heat exchanger HE-1 preferably comprises: an inlet for cooling medium stream CMS2 having a pressure PCMS2 and the temperature TCMS2 at the entrance of the inlet; an outlet for cooling medium stream CMS3 having a pressure p C MS3 and a temperature Tc ss at the exit of the outlet; an inlet for a heat transfer material stream HTMS1 at a pressure PHTMSI and the temperature THTMSI at the entrance of the inlet; and an outlet for heat transfer medium stream HTMS2 having a pressure PHTMS2 and a temperature T H TMS2 at the exit of the outlet
  • heat exchanger HE1 preferably is an indirect heat exchanger, such as an evaporator, in particularly HE1 is preferably a tubular heat exchanger, preferably shell- tube-heat exchanger, double-pipe heat exchanger and drip-type-heat exchanger, or a plate heat exchanger. Most preferably, heat exchanger HE1 is a shell-tube-heat exchanger or a plate heat exchanger.
  • heat exchanger HE1 is preferably designed in a manner so that following requirement are fulfilled: the temperature T C MS2 is in the range of 25 to 120, preferably 30 to 100 and more preferably 40 to 70°C. the temperature T H TMS2 is approximately 0.1 to 50 K, preferably 0.5 to 25 K and more preferably 1 to 10 K higher than THTMSI. heat transfer material HTM1 in heat transfer material stream HTMS1 undergoes at least a partial phase transition from the liquid to the gas state.
  • Cooling medium stream CMS3 may need to be subjected to an additional cooling step 1c), which is preferably conducted in a heat exchanger HE-CMS, which is preferably a water or air cooler, with the effect that same properties as cooling medium stream CMS1 are conferred upon cooling medium stream CMS3, in order to recycle cooling medium stream CMS3 as cooling medium stream CMS1.
  • HE-CMS heat exchanger
  • HE-CMS water or air cooler
  • thermal energy is transferred to the heat transfer material stream HTMS1 to obtain a heat transfer stream HTMS2 having an increased thermal energy compared to heat transfer medium stream HTMS1.
  • heat transfer material HTM1 is preferably selected from the materials listed above, so that a phase transition can occur at the temperatures and pressures which are prevalent in heat exchanger HE1 .
  • Step 2) Compression of HTMS2 to HTMS3
  • thermal energy is preferably further transferred in step 2) by compressing heat transfer medium stream HTMS2 in the first heat pump HP1 to obtain a heat transfer medium stream HTMS3 having a higher pressure than heat transfer medium stream HTMS2. Compression is preferably affected in a compressor.
  • a compressor is a device for increasing the pressure of an at least partially gaseous fluid.
  • the compressor is typically a positive displacement compressor or a dynamic compressor.
  • Positive displacement compressors comprise reciprocating compressors that use pistons driven by a crankshaft to deliver fluids at higher pressures. Reciprocating compressors can be single or multi-staged. Positive displacement compressors also comprise rotary screw compressors, conical screw compressors, rotary vane compressors, rolling piston compressors or scroll compressors.
  • the compressor can also be a dynamic compressor, such as a centrifugal compressor or an axial compressor.
  • the compressor is a rotary screw compressor, a centrifugal compressor, a piston compressor or an axial flow compressor.
  • Compression can be conducted in one compressor or a series of compressors, depending on the desired pressure increase of the heat transfer material HTM1 .
  • the heat transfer material HTM1 enters the compression step as heat transfer material stream HTMS2 at a pressure PHTMS2 and a temperature THTSM2 and leaves the compression step as heat transfer material HTMS3 at a pressure PHTMS3 and a temperature THTMSS.
  • the pressure increase Ap (PHTMS3-PHTMS2) in the compression step is typically chosen so that the temperature of heat transfer medium stream is increased to a temperature which can induce a liquid-to-gas phase transition in the heat transfer material HTM2 of the second heat pump HP2.
  • the pressure is increased so that HTMS3 is 50 K or more, more preferably 80 K or more and most preferably 100 K or more above the boiling temperature of heat transfer material HTM2 in heat pump HP2 at the pressure of PSHTMSI to allow for the compensation of any heat losses and to enable the complete evaporation of heat transfer material HTM2 in heat pump HP2.
  • thermal energy is further transferred from heat pump HP1 to heat pump HP2 in a step 3) by transferring thermal energy from heat transfer medium stream HTMS3 of the first heat pump HP1 to a second heat transfer medium stream SHTMS1 of the second heat pump HP2 to obtain a second heat transfer medium stream SHTMS2 having an increased thermal energy compared to the second heat transfer medium stream SHTMS1 and a heat transfer medium stream HTMS4 having a reduced thermal energy content compared to heat transfer medium stream HTMS3.
  • Heat pump HP2 is
  • the transfer of heat from heat transfer material stream HTMS3 to the second heat transfer material stream HTMS1 is preferably affected by a heat exchanger HE2.
  • Heat exchanger HE2 is a device that is used to transfer thermal energy in the form of heat between heat transfer material stream HTMS3 and a second heat transfer medium stream SHTMS1 to obtain a second heat transfer medium stream SHTMS2 having an increased thermal energy compared to heat transfer medium SHTMS1 and a heat transfer material stream HTMS4 having a reduced thermal energy compared to heat transfer material stream HTMS3.
  • the heat exchanger HE2 is preferably an indirect heat exchanger.
  • HE2 When heat exchanger HE2 is an indirect heat exchanger, HE2 preferably comprises: an inlet for heat transfer medium stream HTMS3 having a pressure PHTMSS and the temperature T HTMSS at the entrance of the inlet; an outlet for heat transfer medium stream HTMS3 having a pressure PHTMSS and a temperature T HTMSS at the exit of the outlet; an inlet for a second heat transfer medium stream SHTMS1 having a pressure PSHTMSI and the temperature TSHTMSI at the entrance of the inlet; and an outlet for a second heat transfer medium stream SHTMS2 having a pressure PSHTMS? and a temperature TSHTMS2 at the exit of the outlet.
  • the heat exchanger HE2 is a shell-and- tube exchanger or a plate exchanger.
  • Heat exchanger HE2 is preferably designed in a manner so that following requirement are fulfilled: the temperature THTMSS is substantially higher than the boiling point of heat transfer material HTM2 in heat pump HP2 at the adjusted pressure, preferably 5 to 200 K or more, preferably 5 to 50 K or more, and most preferably 5 to 25K or more, higher than the boiling point of heat transfer material SHTM1 at the pressure PSHTMSI .
  • the temperature TSHTMS2 is approximately 0.1 to 50 K, preferably 0.3 to 15 K and more preferably 1 to 5 K higher than TSHTMSI heat transfer material HTM2 in heat pump HP2 in the second heat transfer material stream SHTMS1 undergoes at least a partial phase transition from the liquid to the gas state.
  • the pressure PSHTMSI is preferably in the range of about 1 bar. It is possible that the pressure PSHTMSI is below atmospheric pressure, such as 0.1 to 1 bar, but in a preferred embodiment, the pressure PSHTMSI on the side of the second heat transfer material SHTM is at atmospheric pressure or above, preferably in the range 0.7 to 2 bar, more preferably 0.8 to 1.5 bar and more preferably 0.9 to 1.2bar.
  • the heat transfer material HTM2 is a working fluid used in heat pump HP2 to transport thermal energy from heat exchanger HE2 to heat exchanger HE-R.
  • the heat transfer material HTM2 can undergo at least a partial phase transition from the liquid to the gas state upon transfer of thermal energy in heat exchanger HE2.
  • the heat transfer material HTM2 can also undergo at least a partial phase transition from the gas to the liquid state upon transfer of thermal energy in heat exchanger HE-R.
  • Heat transfer material HTM2 is preferably a substance whose boiling point at PSHTMSI is lower than THTMSS at PHTMSS and below the temperature at which the regenerator is operated.
  • any other material whose boiling point at the pressure PSHTMSI is below 150°C, preferably 140°C and more preferably below 130°C is preferred.
  • the most preferred heat transfer material HTM2 is water because water can at least partially undergo a phase transition to steam in heat exchanger HE2.
  • the second heat transfer material streams SHTMS 1 to 5 are streams of heat transfer material 2 in different stages of the heat pump HP2, wherein: the second heat transfer material stream SHTMS1 is the stream of heat transfer material HTM2 entering step 3); the second heat transfer material stream SHTMS2 is the stream of heat transfer material HTM2 exiting step 3) and entering compression step 4); the second heat transfer material stream SHTMS3 is the stream of heat transfer material HTM2 exiting compression step 4) and entering step 5); the second heat transfer material stream SHTMS4 is the stream of heat transfer material HTM2 exiting step 5) and which optionally can enter recycling step R2); the second heat transfer material stream SHTMS5 is the stream of heat transfer material HTM2 exiting recycling step R2) and which can be recycled to step 3) as the second heat transfer material stream SHTMS1.
  • the transfer of heat from heat pump HP1 to heat pump HP2, specifically to the second heat transfer material stream SHTMS2, is preferably followed by a compression step 4) in which the second heat transfer medium stream SHTMS2 in the second heat pump HP2 is compressed to obtain a second heat transfer medium stream SHTMS3 having a higher pressure than the second heat transfer medium stream SHTMS2. Compression is preferably affected in a compressor.
  • a compressor is a device for increasing the pressure of an at least partially gaseous fluid.
  • the compressor is typically a positive displacement compressor or a dynamic compressor.
  • Positive displacement compressors comprise reciprocating compressors that use pistons driven by a crankshaft to deliver fluids at higher pressures. Reciprocating compressors can be single or multi-staged. Positive displacement compressors also comprise rotary screw compressors, conical screw compressors, rotary vane compressors, rolling piston compressors or scroll compressors.
  • the compressor can also be a dynamic compressor, such as a centrifugal compressor or an axial compressor.
  • the compressor is a rotary screw compressor, a centrifugal compressor, a piston compressor, or an axial flow compressor.
  • Compression can be conducted in one compressor or a series of compressors, depending on the desired pressure increase of the heat transfer material HTM2.
  • the heat transfer material HTM2 enters the compression step as heat transfer material stream SHTMS2 at a pressure PSHTMS2 and a temperature TSHTSM? and leaves the compression step as heat transfer material stream SHTMS3 at a pressure PSHTMSS and a temperature TSHTMSS.
  • the pressure increase Ap (PSHTMS3-PSHTMS2) in the compression step is typically 1 to 20 bar, preferably 1.2 to 10 bar and more preferably 1.5 to 3 bar and the accompanying temperature increase is preferably 20 to 2000K, more preferably 25 to 6 K and most preferably 30 to 50 K.
  • the compression step is conducted in a series of two or more compressors and the heat transfer material HTM2 is water.
  • an additional stream of heat transfer material HTM2 is additionally fed after each of the compressors in series to increase the amount of gaseous heat transfer material HTM2 produced at the expense of lowering the temperature of the stream. In this way it can be procured that enough steam is generated for regeneration step c).
  • the addition of further heat transfer material HTM2 is energetically favorable compared to a scenario producing the same amount of gaseous heat transfer material HMT2, where no additional heat transfer material HTM2 is introduced after a compression step.
  • saturated steam is produced, and used for the heating in reboiler HE-R. By injecting water in between the compressor sections helps to lower the superheating of the steam.
  • thermal energy is transferred to the regeneration step c) in step 5) by transferring thermal energy from the second heat transfer medium stream SHTMS3 of the second heat pump HP2 to the regeneration step c) to obtain a second heat transfer medium stream SHTMS4 having a reduced thermal energy content compared to SHTMS3.
  • the transfer of thermal energy from the second heat transfer material stream HTMS3 to the regeneration step c) is carried out in a heat exchanger HE-R in which the laden absorbent A2 obtained in step b) is heated prior to entering the regeneration step c).
  • Heat exchanger HE-R can replace or be in addition to the crossflow heat exchanger used to transfer heat from regenerated absorbent A3 to laden absorbent A2 prior to entering the regeneration step c).
  • the heat exchanger HE-R is preferably an indirect heat exchanger.
  • HE-R When heat exchanger HE-R is an indirect heat exchanger, HE-R preferably comprises: an inlet for laden absorbent A2; an outlet for laden absorbent A2 having an increased thermal energy compared to laden absorbent A2 at the inlet of heat exchanger HE-R; an inlet for a second heat transfer medium stream SHTMS1 having a pressure PSHTMSI and the temperature TSHTMSI at the entrance of the inlet; and an outlet for a second heat transfer medium stream SHTMS2 having a pressure PSHTMS? and a temperature TSHTMS2 at the exit of the outlet.
  • the heat exchanger HE-R is a shell-and- tube exchanger or a plate exchanger.
  • This embodiment may be particularly useful in the case of flue gas, when an intermediate evaporation or flashing step is conducted after the crossflow heat exchanger HE-CF.
  • the at least partially laden absorbent stream A2 can be re-heated prior to entering the regenerator.
  • thermal energy is directly transferred from the second heat transfer medium stream SHTMS3 to the bottoms of the regenerator in regeneration step c).
  • the transfer of thermal energy is affected through a heat exchanger HE-R connected to the bottoms of the regenerator, in which heat exchange proceeds indirectly.
  • the indirect heat exchanger HE-R is the reboiler.
  • the reboiler is typically comprises an inlet connected to the bottom of the regenerator from which an absorbent stream AS1 enters the reboiler and outlet connected to an inlet at the bottom of the regenerator through which an absorbent stream AS2 exits the reboiler and reenters the regenerator.
  • the reboiler also comprises an inlet through which the second heat transfer material stream SHTMS3 enters and an outlet through which the second heat transfer material stream SHTMS4 exits the reboiler.
  • HE-R is preferably a reboiler selected from the group consisting of kettle type reboilers, thermosyphon reboilers and forced circulation reboilers.
  • the method of the present invention comprises an additional recycling step R1) in which the heat transfer material stream HTMS4 obtained in step 3) is expanded to obtain a heat transfer medium stream HTMS5 having a reduced pressure compared to heat transfer material stream HTMS4 and which is at least partially recycled to step 1) as heat transfer material stream HTMS1.
  • Expansion is preferably affected by to reduce the pressure PHTMS4 of heat transfer medium stream HTMS4 to a pressure PHTMSS of heat transfer medium stream HTMS5 .
  • Expansion is preferably affected by a thermal expansion valve.
  • Thermal expansion valves which can be used in the recycling step R1) are described in the Wikipedia article "Thermal Expansion Valve” at https://en. wikipe- dia.org/wiki/Thermal expansion valve.
  • Pressure reduction Ap from PHTMS4 to PHTMSS usually results in an adiabatic flash evaporation of a part of heat transfer medium stream HTMS4 and the auto-refrigeration effect of the adiabatic flash evaporation lowers the temperature of the heat transfer medium stream HTMS4.
  • the expansion valve is preferably operated and designed in a manner that PHTMSS equals PHTMSI and THTMSS equals THTMSI SO that the heat transfer material stream HTMS5 can be preferably recycled to step 1 as heat transfer material stream HTMS1.
  • the method of the present invention comprises an additional recycling step R2) in which the second heat transfer material stream SHTMS4 obtained in step 5) is expanded to obtain a second heat transfer medium stream SHTMS5 having a reduced pressure compared to the second heat transfer material stream SHTMS4 and which is at least partially recycled to step 3) as second heat transfer material stream SHTMS1.
  • Expansion is preferably affected by to reduce the pressure PSHTMS4 of heat transfer medium stream SHTMS4 to pressure PSHTMSI of heat transfer medium stream SHTMS1.
  • Expansion is preferably affected by a thermal expansion valve.
  • Thermal expansion valves which can be used in step 4) are described in the Wikipedia article "Thermal Expansion Valve” at https://en.wikipedia.org/wiki/Thermal expansion valve.
  • Pressure reduction Ap from PSHTMS4 to PSHTMSS results in the adiabatic flash evaporation of a part of heat transfer medium stream SHTMS4 and the auto-refrigeration effect of the adiabatic flash evaporation lowers the temperature of the heat transfer medium stream SHTMS4.
  • the expansion valve is preferably operated and designed in a manner that PSHTMSS equals PSHTMSI and TSHTMSS equals TSHTMSI
  • Heat transfer medium stream SHTMS5 is preferably recycled to step 1) of the evaporation process as heat transfer material stream SHTMS1.
  • the execution of at least one of the additional recycling steps R1 and R2 has the advantage that the heat transfer materials HTM1 and HTM2 can be reused in a closed cycle heat pump in order to save material costs or to prevent a contamination of the environment which would be associated with a loss of heat transfer material HTM1 or HTM2 in case a environmentally detrimental heat transfer material HTM1 or HTM2 is selected.
  • the heat transfer material HTM2 is water/steam, it is not mandatory to expand the second heat transfer material stream SHTM4 to recycle the water as the water may be discarded to the environment or used to transfer heat to other processes. In this case, it is preferred not to recycle the second heat transfer material stream SHTMS4 directly to heat exchanger HE-1.
  • the method of the present invention also comprises recycling step R2 if the heat transfer material HTM2 is water or another heat transfer material HTM2 in order to save resources, especially if the availability of heat transfer material HTM2 is limited at the production site.
  • the present invention may also comprise more than two heat pumps which are connected in series, such as three or four heat pumps, whereby the condenser of one heat pump is the evaporator of the subsequent heat pump.
  • the last heat pump of the series of more than two heat pumps will fulfill the function of heat pump HP2 in a series of two heat pumps.
  • the heat transfer material of the last heat pump in series is preferably water for the same reasons, water is preferred heat transfer material HTM2 in heat pump HP2.
  • fluid stream FS2 is deacidified in an absorption step b) in which the cooled fluid stream FS2 is contacted with an absorbent A1 in an absorber to obtain an absorbent A2 laden with acid gases and an at least partly deacidified fluid stream.
  • the absorbent comprises at least one amine.
  • R 1 is selected from C2-C6-hydroxyalkyl groups, Ci-C6-alkoxy-C2-C6-alkyl groups, hydroxy-Ci-C6-alkoxy-C2- C 6 -alkyl groups and 1 -piperazinyl-C 2 -C6-alkyl groups, and R 2 is independently selected from H, Ci-C 6 -alkyl groups and C2-C6-hydroxyalkyl groups;
  • R 3 R 4 N-X-NR 5 R 6 (II) in which R 3 , R 4 , R 5 and R 6 are independently selected from H, Ci-Ce-alkyl groups, C2-Ce-hydroxyalkyl groups, Ci-Ce- alkoxy-C2-Ce-alkyl groups and C2-Ce-ami noalkyl groups, and X is a C2-C6-alkylene group, -X 1 -NR 7 -X 2 - or -X 1 -O-X 2 -, in which X 1 and X 2 are independently C2-C6-alkylene groups and R 7 is H, a Ci-Ce-alkyl group, C2-C6-hydroxyalkyl group or C2-C6-aminoalkyl group; ill) 5- to 7-membered saturated heterocycles which have at least one nitrogen atom in the ring and may comprise one or two further heteroatoms selected from nitrogen and oxygen in the ring, and iv) mixtures thereof.
  • 2-aminoethanol (monoethanolamine), 2-(methylamino)ethanol, 2-(ethylamino)ethanol, 2-(n-butylamino)ethanol, 2- amino-2-methylpropanol, N-(2-aminoethyl)piperazine, methyldiethanolamine, ethyldiethanolamine, dimethylaminopropanol, t-butylaminoethoxyethanol (TBAEE), 2-amino-2-methylpropanol, diisoproanolamine (DIPA);
  • the absorbent comprises at least one of the amines monoethanolamine (MEA), methylaminopropylamine (MAPA), piperazine (PIP), diethanolamine (DEA), triethanolamine (TEA), diethylethanolamine (DEEA), diisopropanolamine (DIPA), aminoethoxyethanol (AEE), tert-butylaminoethoxyethanol (TBAEE), dimethylaminopropanol (DI MAP) and methyldiethanolamine (MDEA), triethylendiamine (TEDA) or mixtures thereof.
  • amines that may be introduced into the process are tert-butylaminopropanediol, tert-butylaminoethoxyethyl- morpholine, tert-butylaminoethylmorpholine, methoxyethoxyethoxyethyl-tert-butylamine, tert-butylaminoethylpyrroli- done.
  • the amine is preferably a sterically hindered amine or a tertiary amine.
  • a sterically hindered amine is a secondary amine in which the amine nitrogen is bonded to at least one secondary carbon atom and/or at least one tertiary carbon atom; or a primary amine in which the amine nitrogen is bonded to a tertiary carbon atom.
  • a preferred sterically hindered amine is t-butylaminoethoxyethanol.
  • a preferred tertiary amine is methyldiethanolamine and triethylendiamine (TEDA).
  • the absorbent preferably additionally comprises an activator when the amine present in the absorbent is a sterically hindered amine or a tertiary amine.
  • the activator is generally a sterically unhindered primary or secondary amine. In these sterically unhindered amines, the amine nitrogen of at least one amino group is bonded only to primary carbon atoms and hydrogen atoms. If the aim is merely to remove a portion of the gases present in the fluid stream, for example the selective removal of H2S from a fluid stream comprising H2S and CO2, the absorbent preferably does not comprise any activator.
  • the sterically unhindered primary or secondary amine which can be used as activator is selected, for example, from alkanolamines, such as monoethanolamine (MEA), diethanolamine (DEA), ethylaminoethanol, 1-amino-2-methyl- propan-2-ol, 2-amino-1-butanol, 2-(2-aminoethoxy)ethanol and 2-(2-aminoethoxy)ethanamine, polyamines, such as hexamethylenediamine, 1 ,4-diaminobutane, 1 ,3-diaminopropane, 3-(methylamino)propylamine (MAPA), N-(2- hydroxyethyl)ethylenediamine, 3-(dimethylamino)propylamine (DMAPA), 3-(diethylamino)propylamine, N,N'-bis(2- hydroxyethyl)ethylenediamine, 5-, 6- or 7-membered saturated heterocycles having at least one NH
  • 5-, 6- or 7-membered saturated heterocycles which have at least one NH group in the ring and may comprise one or two further heteroatoms selected from nitrogen and oxygen in the ring.
  • piperazine is particularly preferred.
  • the molar ratio of activator to sterically hindered amine or tertiary amine is preferably in the range from 0.05 to 1 .0, more preferably in the range from 0.05 to 0.7.
  • the absorbent generally comprises 10% to 60% by weight of amine.
  • the absorbent comprises the tertiary amine methyldiethanolamine and the activator piperazine.
  • the absorbent comprises
  • amine A) is triethylendiamine (TEDA) and activator amine B) is piperazine.
  • the absorbent may additionally comprise physical solvents.
  • Suitable physical solvents are, for example, N- methylpyrrolidone, tetramethylenesulfone, oligoethylene glycol dialkyl ethers such as oligoethylene glycol methyl isopropyl ether (SEPASOLV MPE), oligoethylene glycol dimethyl ether (SELEXOL).
  • the physical solvent is generally present in the absorbent in amounts of 1% to 60% by weight, preferably 10% to 50% by weight, especially 20% to 40% by weight.
  • the absorbent comprises less than 10% by weight, for example less than 5% by weight, in particular less than 2% by weight of inorganic basic salts, such as potassium carbonate for example.
  • the absorbent may also comprise additives, such as corrosion inhibitors, antioxidants, enzymes, antifoams etc.
  • additives such as corrosion inhibitors, antioxidants, enzymes, antifoams etc.
  • the amount of such additives is in the range of about 0.01-3% by weight of the absorbent.
  • the absorber may be supplied with fresh absorbent, or the absorber may be supplied with absorbent regenerated in the recycling step c).
  • the supply of fresh absorbent means that the components of the absorbent are yet to pass through steps b) to d).
  • the supply of regenerated absorbent requires at least a portion of the components of the absorbent to have passed through steps b) to d).
  • the absorbent is preferably aqueous. This means that the wide variety of different constituents of the absorbent, such as amine, methanol, physical solvents, additives, may be mixed with water in the amounts mentioned above.
  • the fluid stream FS2 is preferably contacted with the absorbent in step b) in an absorber.
  • the absorber is preferably an absorption tower or an absorption column, for example a column with random packing or structured packing or a tray column.
  • the absorber generally comprises an absorption zone and optionally a rescrubbing zone.
  • the absorption zone is deemed to be the section of the absorption column in which the fluid stream comes into mass transfer contact with the absorbent.
  • the fluid stream is preferably contacted in countercurrent with the absorbent in the absorption zone.
  • the absorption zone generally comprises internals, for example random packings, structured packings and/or trays, such as valve trays, bubble-cap trays, Thormann trays or sieve trays.
  • the height of the random packings/struc- tured packings of the absorption zone is preferably in the range from 5 to 20 m, more preferably in the range from 6 to 15 m and most preferably in the range from 8 to 14 m.
  • the number of trays in the absorption zone is preferably in the range from 8 to 30, more preferably 12 to 25 and most preferably 15 to 23 trays.
  • the absorption zone may be divided into one or more sections, preferably 2 to 4 sections. Bearing and holding trays and/or distributor trays may be disposed between the individual sections of the absorption zone, and these improve the distribution of the absorbent over the entire cross section of the column.
  • the temperature of the absorbent introduced into the absorption zone is generally about 0 to 60°C, preferably 10 to 50°C and more preferably 25 to 50°C.
  • the pressure in the absorber depends on the pressure and the type of fluid stream FS2 entering the absorber. When fluid stream FS2 is a synthesis gas, the pressure in the absorber is typically in the range from 5 to 120 bar, more preferably 10 to 100 bar and most preferably 10 to 60 bar has.
  • the pressure in the absorber is typically preferably in the range of 0.7 to 1 .5 bar, more preferably 0.8 to 1.3 bar and more preferably 0.9 to 1.2 bar. Most preferably, the absorber is operated at atmospheric pressure, when fluid stream FS2 is a flue gas.
  • the feed point for the fluid stream introduced is preferably below or in the lower region of the absorption zone.
  • the feed is preferably evenly distributed over the cross-section of the absorber via a gas distributor.
  • the absorber may comprise one or more feed points for the absorbent introduced.
  • the absorber may comprise a feed point for fresh absorbent A1 and a feed point for regenerated absorbent A3.
  • Fresh and regenerated absorbent may alternatively be fed into the absorber together via one feed point.
  • the one or more feed points are preferably above or in the upper region of the absorption zone. It is also possible to feed in individual constituents of the absorbent, such as make-up water, via the feed point for fresh absorbent.
  • the feed is preferably between the absorber zone and the rescrubbing zone.
  • the contacting of the fluid stream with the absorbent in the absorption zone affords an at least partly deacidified fluid stream FS3 and an absorbent laden with acid gases.
  • a demister may be mounted in the region of the draw point, in order to separate out any liquid residues of the absorbent or of the scrubbing agent from the exiting fluid stream.
  • the at least partly deacidified fluid stream FS3 may optionally be contacted with a scrubbing liquid in one or more rescrubbing zones (collectively referred to as "rescrubbing zone”).
  • the scrubbing liquid is more preferably an aqueous liquid.
  • the scrubbing liquid may be a liquid intrinsic to the process, i.e., an aqueous liquid obtained elsewhere in the process, or aqueous liquids supplied from the outside.
  • the scrubbing liquid comprises a condensate (called absorber top condensate) formed in a downstream cooling operation on the deacidified fluid stream and/or fresh water.
  • the rescrubbing zone is generally a section of the absorber above the feed point of the absorbent.
  • the rescrubbing zone preferably has random packings, structured packings and/or trays to intensify the contact between the fluid stream and the scrubbing liquid.
  • the rescrubbing zone especially has trays, especially valve trays, bubble-cap trays, Thormann trays or sieve trays.
  • the rescrubbing zone comprises preferably 1 to 7, more preferably 2 to 6 and most preferably 3 to 5 trays, or a packing height (random packings/structured packings) of preferably 1 to 6 m, more preferably 2 to 5 and most preferably 2 to 3 m.
  • the scrubbing liquid is generally introduced above the rescrubbing zone or into the upper region of the rescrubbing zone.
  • the scrubbing liquids used may be the abovementioned scrubbing liquids.
  • the scrubbing liquid may be recycled via the rescrubbing zone. This is achieved by collecting the scrubbing liquid below the rescrubbing zone, for example by means of a suitable collection tray, and pumping it to the upper end of the rescrubbing zone by means of a pump.
  • the recycled scrubbing liquid may be cooled, preferably to a temperature of from 20°C to 70°C, in particular 30°C to 60°C. This is advantageously achieved by recirculating the scrubbing liquid through a cooler.
  • a substream of the scrubbing liquid is preferably discharged from the rescrubbing zone.
  • a scrubbing liquid By the contacting of the at least partly deacidified fluid stream FS3 with a scrubbing liquid, it is possible to scrub out entrained absorbent constituents, such as amines.
  • the contacting with an aqueous scrubbing liquid can additionally improve the water balance of the process when more water is discharged via the exiting streams than is introduced via the entering streams.
  • a deacidified fluid stream FS3, as described above, is preferably drawn off via a draw point in the upper part of the absorber.
  • the deacidified fluid stream FS3 may be guided through a condenser.
  • Condensers used may, for example, be condensers having cooling coils or helical tubes, plate heat exchangers, jacketed tube condensers and shell and tube heat exchangers.
  • the condenser is generally operated at a temperature in the range from 10 to 60°C, preferably 20 to 50°C, more preferably 20 to 30°C.
  • the water content of the deacidified fluid stream is generally 80-100% of the saturation concentration of water in the fluid stream under the existing temperature and pressure conditions.
  • Step b) affords an absorbent A2 at least partially laden with acid gases.
  • the laden absorbent A2 may be fed directly to the regeneration step c).
  • an expansion step is first conducted on the laden absorbent A2 before it is introduced into the regeneration step c).
  • the laden adsorbent A2 is generally guided into one or more expansion vessels.
  • the laden absorbent can be expanded through a throttle valve into an expansion vessel.
  • fluid stream FS2 is a syngas
  • the laden adsorbent is preferably expanded to a pressure of 3 to 15 bar, preferably 4 to 12 and more preferably 5 to 10 bar.
  • the expansion generally leads to the desorption the so-called flash gas.
  • the flash gas may be guided back into the absorption by means of a compressor or incinerated for energy generation or flared off in situ.
  • the laden absorbent is preferably pumped to an expansion vessel which is located downstream of a crossflow heat exchanger HE-CF.
  • the pump usually increases the pressure of the fluid stream FS2 by approximately 2 to 8 barg so it can be expanded to an expansion vessel which is preferably operating slightly above the pressure of the regenerator.
  • the effect of the expansion step is usually enhanced by the temperature increase of the fluid stream FS2 when passing the crossflow heat exchanger HE-CF.
  • the performance of an additional expansion step has the advantage that at least part of the oxygen comprised in fluid stream FS2 may be flashed-off which has a negative impact on the required purity of CO2.
  • the flash vessel is generally a vessel free of any particular internals.
  • the flash vessel is preferably what is called a flash drum.
  • Alternative flash vessels include columns having internals, for example random packings, structured packings, or trays.
  • a demister may preferably be disposed in turn in the region of the gas draw. If required, the acid gases present may be separated from the flash gas in a further absorption column. Typically, for this purpose, a substream of the regenerated solvent is supplied to the additional absorption column.
  • the absorbent A2 at least partly laden with the acid gases that have not been converted to the gas phase is drawn off and is generally guided into regeneration step c).
  • the adsorbent at least partly laden with acid gases A2 is fed into the regeneration step C), in which at least a portion of the laden absorbent A2 obtained from step b) is regenerated in a regenerator to obtain an at least partly regenerated absorbent A3 and a gaseous stream GS comprising at least one acid gas.
  • the gaseous stream GS may comprise residual amounts of water which have not been separated off in the rescrubbing zone.
  • the adsorbent A2 at least partly laden with acid gases is preferably guided through a crossflow heat exchanger HE-CF.
  • the absorbent A2 at least partly laden with acid gases is preferably heated to a temperature in the range from 50 to 150°C, more preferably 70 to 130°C and most preferably 80 to 110°C.
  • the regenerated absorbent A3 drawn from the bottom of the regenerator is used as heating medium in the heat exchanger HE-CF.
  • This embodiment has the advantage that the thermal energy of the regenerated absorbent A3 from stage c) can be used to heat the laden absorbent A2 from step b) in heat exchanger HE-CF. In this way, it is possible to further reduce the energy costs of the overall process and to reduce the energy requirement in the reboiler of regeneration step c).
  • the second heat transfer material stream SHTMS3 is used as a heating medium in a heat exchanger HE-R which is in addition to or a replacement for the crossflow heat exchanger HE-CF.
  • the regeneration step is conducted in a regenerator.
  • the regenerator is generally configured as a stripping column.
  • the regenerator preferably comprises a regeneration zone and a reboiler.
  • the regenerator is preferably operated at a top pressure in the range from 0.5 to 5 bar, preferably 0.7 to 4 and more preferably 0.9 to 2.5 bar.
  • a demister is preferably mounted in the region of the gas draw.
  • the regenerator generally has a regeneration zone disposed above the bottom and below the rescrubbing zone.
  • the regeneration zone is regarded as the region of the regenerator with which the laden absorbent comes into contact with the steam which is produced in the reboiler.
  • the regeneration zone generally comprises internals, for example random packings, structured packings and/or trays, such as valve trays, bubble-cap trays, Thormann trays or sieve trays.
  • the height of the structured pack- ings/random packings in the regeneration zone is preferably in the range from 5 to 15 m, more preferably in the range from 6 to 12 m and most preferably in the range from 8 to 12 m.
  • the number of trays in the regeneration zone is preferably in the range from 10 to 30, more preferably 15 to 25 and most preferably 17 to 23 trays.
  • the regeneration zone may in turn be divided into multiple sections, preferably 2 to 4. Bearing and holding trays and/or distributor trays may be disposed between the sections of the regeneration zone, and these improve the distribution of liquid over the entire cross section of the regenerator.
  • the laden absorbent A2 is preferably introduced into the regenerator in the upper region or above the regeneration zone and below the rescrubbing zone.
  • the vapor generated in the evaporator is generally operated in countercurrent to the absorbent flowing downward through the regeneration zone.
  • the zone of the regenerator beneath the regeneration zone is generally referred to as the bottom.
  • the absorbent is typically collected and (I) fed as absorbent stream AS1 to the reboiler HE-R via pipelines via a liquid draw in the lower region of the regenerator, and/or (II) partly recycled into the absorber as regenerated absorbent A3.
  • the bottom may be divided by a collecting tray disposed between the bottom draw and the feed point for the steam produced in the evaporator.
  • At least a portion of the regenerated absorbent A3 is guided from the bottom draw of the regenerator into the reboiler as absorbent stream AS1 .
  • the bottom draw from the regenerator is guided completely into the reboiler as absorbent stream AS1.
  • the reboiler HE-R is typically a kettle type reboiler, natural circulation reboiler or thermosiphon reboiler or a forced circulation reboiler.
  • the reboiler HE-R of the regenerator is preferably disposed outside the regenerator and connected to the bottom draw via pipelines.
  • the reboiler HE-R is generally operated at temperatures in the range from 100 to 150°C, preferably 105 to 140°C and most preferably 110 to 130°C.
  • absorbent stream AS2 is preferably fed to the regenerator beneath the regeneration zone, preferably into the bottom of the regenerator.
  • the steam produced in the reboiler is preferably fed in beneath the collecting tray.
  • the regenerator has a rescrubbing zone above the regeneration zone, especially preferably above the feed point for the laden absorbent A2.
  • the rescrubbing zone generally takes the form of a section of the regenerator disposed above the regeneration zone.
  • the rescrubbing zone preferably has internals, especially random packings, structured packings and/or trays to intensify the contact between the fluid stream and the scrubbing liquid.
  • the scrubbing section has trays, especially valve trays or bubble-cap trays.
  • the internals are random packings and/or structured packings.
  • the packing height (random packings/structured packings) is preferably within a range from 1 to 10, more preferably 2 to 8 and most preferably 3 to 6 m.
  • the rescrubbing zone has trays, especially valve trays or bubble-cap trays, the number of trays preferably being in the range from 2 to 10, more preferably 2 to 8 and most preferably 2 to 6 trays.
  • a scrubbing liquid may be introduced into the upper region of the rescrubbing zone or above the rescrubbing zone.
  • the scrubbing liquid used is generally an aqueous or slightly acidic aqueous solution, especially water.
  • the temperature of the scrubbing liquid is generally in the range from 10 to 60°C, preferably in the range from 20 to 55°C and more preferably 30 to 40°C.
  • entrained residual amounts of amines may be scrubbed out of the absorbent, such that the acidic off gas GS leaving the regenerator is essentially free of amines.
  • the water content of the gas stream which is obtained at the top of the regenerator may additionally be reduced since the contact with the colder scrubbing agent can result in condensation of a portion of the vaporous water.
  • the acid gas stream GS from the regenerator is introduced into a condensation step.
  • a condensate comprising water is condensed out of the gaseous stream (condensate outlet).
  • the uncondensed gas phase is preferably discharged to a compression step, as further described below.
  • the condensation step is preferably conducted in such a way that the gaseous stream GS from stage c) is guided through one or more condensers (regenerator top condensers).
  • the top condensers generally comprise a heat exchanger and a vessel in which the liquid phase can be separated from the gas phase (phase separation vessel). However, heat exchanger and vessel may also be integrated in one component.
  • the regenerator top condenser is generally operated in such a way that water will condense, while the acid gases remain predominantly in the gas phase.
  • Regenerator top condensers used may, for example, be condensers having cooling coils or helical tubes, jacketed tube condensers and shell and tube heat exchangers.
  • the regenerator top condenser is generally operated at a temperature in the range from 10 to 60°C, preferably 20 to 55°C, more preferably 30 to 40°C.
  • the gaseous stream GS from stage c) is guided through one regenerator top condenser. It is optionally possible to additionally introduce a scrubbing liquid, as described above, into the regenerator together with the condensate from the condensation step. The introduction can be effected via the same feed point. Scrubbing liquid can alternatively be introduced via a separate feed point.
  • Fluid stream GS preferably comprises CO2.
  • the CO 2 is preferably sequestered in suitable storage locations. Sequestration generally requires that the gaseous CO 2 stream GS is compressed and optionally cooled into a fluid which can be transported through pipelines to its destination or which can be transported as a chemical to its destination where it is utilized for further uses
  • Typical pressures of CO 2 -pressures in pipelines for transportation are 70 to 200 bar, preferably 90 to 150 bar.
  • Typical pressures of CO 2 for transportation by ship, truck or train are 5 to 50 bar, preferably 6 to 40 and more preferably 7 to 35 bar.
  • Compression is usually affected in one or more compressors.
  • the compressor is usually configured to receive the CO 2 comprising gaseous stream GS and compress the gaseous stream to yield a compressed fluid stream CFS.
  • the compressor is typically a positive displacement compressor or a dynamic compressor.
  • Positive displacement compressors comprise reciprocating compressors that use pistons driven by a crankshaft to deliver fluids at higher pressures. Reciprocating compressors can be single or multi-staged.
  • Positive displacement compressors also comprise rotary screw compressors, conical screw compressors, rotary vane compressors, rolling piston compressors or scroll compressors.
  • the compressor can also be a dynamic compressor, such as a centrifugal compressor or an axial compressor.
  • the compressor is a rotary screw compressor, a centrifugal compressor, a piston compressor or an axial flow compressor.
  • the fluid stream CFS is preferably passed through one or more heat exchangers to dissipate the heat from the compressed fluid or to utilize the heat of compression as a heat source for heating other processes or other steps of the gas treatment process.
  • compression may be supplemented by one or more additional refrigeration steps to liquify the CO2.
  • CO2 may be cooled in a heat exchanger which is an evaporator for a heat transfer material, preferably liquid ammonia. The evaporated heat transfer material is then compressed, cooled, and expanded in a tradition refrigeration circuit. It is also possible to combine two or more refrigeration circuits in series, which reduces the energy consumption of refrigeration.
  • CO2 may be compressed and cooled by external water and expansion to the transportation temperature and then compressed.
  • Non-liquefied CO2 is preferably separated a recirculated to the compression step.
  • the energy consumption can be reduced by performing the compression and depressurization (evaporation) in several steps.
  • Drying can occur before, after or after one or more of the compression steps or cooling steps.
  • Drying is preferably conducted in the form of a pressure swing adsorption (PSA) and more preferably in the form of a temperature swing adsorption (TSA), or in the form of a glycol drying operation.
  • PSA pressure swing adsorption
  • TSA temperature swing adsorption
  • PSA or TSA can be conducted by methods known to the person skilled in the art. Standard variant procedures are described, for example, in Nag, Ashis, "Distillation and Hydrocarbon Processing Practices”, PennWell 2016, ISBN 978-1-59370-343-1 or in A. Terrigeol, GPA Europe, Annual Conference, Berlin, Germany, 23rd-25th May, 2012 (https://www.cecachemicals.com/export/sites/ceca/.content/medias/downloads/products/dtm/molecular-sieves-con- taminants-effects-consequences-and-mitigation.pdf).
  • PSA or TSA preference is given to using a zeolite, activated carbon or molecular sieve. Preference is given to using a molecular sieve as solid adsorbent in PSA or TSA.
  • liquid absorbent such as monoethylene glycol (MEG), diethylene glycol (DEG), triethylene glycol (TEG) or tetraethylene glycol (TREG).
  • MEG monoethylene glycol
  • DEG diethylene glycol
  • TEG triethylene glycol
  • TEG tetraethylene glycol
  • TEG is especially preferably used as liquid absorbent.
  • glycol drying operation can be conducted by process variants known to the person skilled in the art. Examples of glycol drying are likewise found, for example, in Nag, Ashis, "Distillation and Hydrocarbon Processing Practices", PennWell 2016, ISBN 978-1-59370-343-1.
  • COS carbonyl sulfide
  • hydrogen sulfide may be removed by installing additional filters and adsorbers.
  • the fluid stream CFS is preferably transported to its storage location or its final utilization.
  • CO 2 may be transported via pipelines or by a carrier, such as truck, train, and ship..
  • Suited storage locations are suited geological formations, such as depleted oil and gas reservoirs, mines and saline or other rock formations.
  • CO2 may also be used by the food industry, the oil industry, and the chemical industry.
  • CO 2 in the food industry is the carbonization of beverages.
  • the regenerated absorbent A3 obtained at the bottom of the regenerator from step c) is returned to the absorption step b).
  • the regenerated absorbent is preferably recycled in one of the feed points of the absorber for the regenerated absorbent as described above.
  • the method of the present invention allows the exploitation of the thermal energy inherent in a heat stream HS1 , in particularly fluid stream FS1, to provide energy for the energy extensive regeneration step c).
  • the use of two or more heat pumps which are connected in series has the advantage that the thermal energy from heat stream HS1, in particularly FS1, can be raised to a level at where it is possible to generate steam in heat pump HP2 which can be used to transfer heat to the regeneration step c).
  • the stream produced in heat pump HP2 can therefore effectively replace process steam usually required as a heat source in the regeneration step c).
  • the use of two heat pumps in series can replace the requirement to have a separate process steam production process installed at the site of the acid gas removal unit or the requirement for steam turbines, such as back pressure turbines or pass-out condensing turbines, to produce process steam.
  • the present invention is therefore particularly useful where process steam is not readily available at the site of an acid gas removal unit.
  • the method according to the present invention may be useful as an alternative method to produce process steam as it allows to use potentially limited process steam resources for other uses or allows to reduce power loss of power plants associated with process steam production.
  • the method of the present invention is an interesting alternative in the design of new power plants coupled to an acid gas removal unit for carbon capture because the requirement to divert energy for steam production to power the recycling step can be reduced.
  • the method of the present invention is a useful method to electrify steam production so that the steam required in the amine gas treating process can be provided by "green” electricity from renewable resources.
  • the last heat transfer material HTM of the last heat pump HP in series is water.
  • the use of water as the last heat transfer material greatly improves the flexibility of the process as excess steam can be diverted to other steam consumers or a steam deficiency can be compensated from other steam providers, e.g., an internal steam providing network.
  • fluctuations in the feed stream FS2 to the absorber can be at least partially compensated. Such fluctuations may result from a reduced demand for the heat stream HS1, the fluid stream FS1 or the fluid stream FS2 producing process. This may be the case when an increased availability of renewable wind and solar energy results in a reduced demand for fossil fuel provided energy.
  • the thermal energy from a gaseous heat stream HS1, in particularly fluid stream FS1 is transferred to the regeneration step via an intermediate cooling loop comprising a direct contact cooler DCC and a cooling material CM.
  • Direct heat exchange has the advantage that the exchange area between the two fluid streams HS1 and CMS1 increases, which reduces thermal resistances and maximizes the thermal efficiency.
  • direct heat exchangers usually have lower operating and capital costs than indirect heat exchangers due to a high heat transfer rate per volume and because fouling and corrosion is usually not a problem.
  • Particular efficiency of the method of the present invention is obtained when: using water as cooling medium in cooling mediums streams CMS1 and CMS2, using ammonia or butane or R1233zd(e) as heat transfer material HTM1; and using water as heat transfer material HTM2.
  • the method of the present invention can be combined with additional heat pumps which are designed to transfer thermal energy from other heat sources present in the gas treating process.
  • additional heat sources include but are not limited to the heat sources HS set out above, including but not limited to: the heat of absorption occurring in the absorber, which can be utilized in an intercooler or by the integration of heat exchangers into the absorber, the heat of absorption in the rescrubbing zone at the top of the absorber, if the rescrubbing zone is equipped with a pump and a cooler, the heat of condensation of condensate at the head of the absorber or the regenerator, the heat of compression in the compression step which is created when compressing gaseous stream GS into a supercritical fluid.
  • the invention is directed to an apparatus for deacidifying a fluid stream according to Claim 17.
  • the figures each show an apparatus for deacidifying a fluid stream, comprising a) an absorber with a. an inlet for fluid stream FS2, b. an outlet for a deacidified fluid stream FS3; c. an inlet for an absorbent stream A1 , d. an inlet for regenerated absorbent stream A3; and e. an outlet for a laden absorbent stream A2 b) a regenerator with a. an inlet for laden absorbent stream A2; b. an outlet for regenerated absorbent stream A3; c. an outlet for an acid gas stream GS; c) a heat pump HP1 , comprising a a.
  • heat exchanger HE1 with a first inlet for heat stream HS1 and an outlet for heat stream HS2 or a first inlet for cooling medium stream CMS2 and an outlet for cooling medium stream CMS3; and a second inlet for heat transfer medium stream HTMS1 and a second outlet for heat transfer medium stream HTMS2; b.
  • heat pump HP2 which is connected to heat pump HP 1 in series by a heat exchanger HE2 with a first inlet for heat transfer medium stream HTMS3 and an outlet for heat transfer medium stream HTMS4 and a second inlet for a second heat transfer medium stream SHTMS1 and a second outlet for a second heat transfer medium stream SHTMS2, and wherein heat pump HP2 additionally comprises; a.
  • one or more compressors connected in series, where the inlet of the first compressor is connected to the second outlet for heat transfer medium stream SHTMS2 from the heat exchanger HE2 and the outlet of the last of the series of compressors has an outlet for compressed heat transfer medium stream SHTMS3; b. one or more optional feeding points for additional heat transfer material HTM2 between the compression steps in order to increase the amount of gaseous heat transfer material HTM2 which can be produced (this embodiment is particularly preferred if the heat transfer material HTM2 is water in order to increase the amount of steam which can be produced in heat pump HP2); c. a heat exchanger HE-R d.
  • heat exchanger HE-R has an inlet for an absorbent stream AS1 connected to the regenerator and an out for an absorbent stream AS2 also connected to the regenerator.
  • Figure 1 shows an embodiment of an apparatus which is suitable for the direct transfer thermal energy from the heat stream HS1 to heat exchanger HE1 of heat pump HP1 where the inlet of heat exchanger HE1 is configured to directly receive heat stream HS1.
  • Figure 2 shows an embodiment of an apparatus which is suitable for the direct transfer of thermal energy from a heat stream HS1, where the heat stream HS1 is the fluid stream FS1.
  • Figure 3 shows an embodiment of an apparatus which is suitable for the indirect heat transfer of thermal energy from heat stream HS1, in this case fluid stream FS1, to heat exchanger HE1 of heat pump HP1 via the intermediate cooling circuit comprising heat exchanger HE-C where the inlet of heat exchanger HE1 is configured to receive the cooling medium stream CMS2.
  • Figure 3 additionally comprises a heat exchanger HE-C, comprising an inlet for heat stream HS1, in this case FS1, and an outlet for heat stream HS2, in this case fluid stream FS2, an inlet for cooling medium stream CMS1 and an outlet for cooling medium stream CMS2.
  • heat exchanger HE-C is configured as a direct contact cooler, which constitutes a preferred embodiment of the present invention.
  • FIG 4 shows a preferred embodiment, which differs from Figure 3 in that heat pump HP2 is configured as an openloop heat pump, which is preferably operated with water as heat transfer material HTM2.
  • the absorber is configured as an absorption column.
  • the absorption column preferably has an absorption zone.
  • the absorption zone is deemed to be the section of an absorption column in which the fluid stream comes into mass transfer contact with the absorbent.
  • the absorption zone preferably comprises internals, preferably random packings, structured packings and/or trays.
  • the absorption zone is preferably divided into two to four packing sections arranged one on top of another that are separated from one another by bearing and holding trays and/or a distributor tray.
  • the height of the structured packings/ran- dom packings in the absorption zone is preferably in the range from 5 to 20 m, more preferably in the range from 6 to 15 m and most preferably in the range from 8 to 14 m.
  • the number of trays in the absorption zone is preferably in the range from 8 to 30, more preferably 12 to 25 and most preferably 15 to 23 trays.
  • the fluid stream FS2 Preferably below or in the lower region of the absorption zone, there is an inlet for the fluid stream FS2 to be deacidified.
  • Fresh absorbent A1 can be fed in via an inlet in the upper region or above the absorption zone.
  • the supply of fresh absorbent may also include the supply of individual constituents of the absorbent, such as make-up water.
  • Regenerated absorbent A3 may be fed in via the same inlet or an inlet which is likewise in the upper region or above the absorption zone.
  • the absorption zone Preferably above the absorption zone, preferably at the top of the absorption column, there is an outlet for the deacidified fluid stream FS3.
  • a demister (not shown) is preferably mounted in the region of the draw point for the deacidified fluid stream.
  • the absorber comprises an additional rescrubbing zone above the absorption zone (not shown).
  • the rescrubbing zone is generally configured as a section of the absorber in the form of a rectifying section disposed above the feed point for the absorbent.
  • the rescrubbing zone preferably has random packings, structured packings and/or trays to intensify the contact between the fluid stream and the scrubbing liquid.
  • the rescrubbing zone especially has trays, especially valve trays, bubble-cap trays, Thormann trays or sieve trays.
  • the rescrubbing zone comprises preferably 1 to 7, more preferably 2 to 6 and most preferably 3 to 5 trays, or a packing height (random packings or structured packings) of preferably 1 to 6 m, more preferably 2 to 5 and most preferably 2 to 3 m.
  • a collecting tray may be disposed beneath the rescrubbing zone, on which scrubbing liquid can be collected and recycled.
  • the recycling is generally affected here by means of a pump (not shown) that pumps the scrubbing liquid from the collecting tray to the feed point.
  • the scrubbing liquid may be cooled by means of a heat exchanger (not shown).
  • a heat exchanger HE-CF between the liquid draw for the laden absorbent in the absorber and the feed for the laden absorbent in the regenerator.
  • the heating medium used for this heat exchanger is preferably the recycle stream of the regenerated absorbent A3 from the bottom of the regenerator to the absorber.
  • the energy demand of the overall process can be reduced.
  • the heat exchanger HE-CF may be configured as a plate heat exchanger or shell and tube heat exchanger.
  • the heating medium used in the heat exchanger is preferably the bottom stream from the regenerator.
  • the outlet for laden absorbent A2 from the absorber is preferably connected via a heat exchanger to the regenerator via pipelines.
  • the regenerator in all figures preferably comprise a regeneration zone, an evaporator, a feed inlet for the laden absorbent A2, a liquid draw (outlet) in the bottom of the regenerator for at least partially regenerates absorbent A3, a rescrubbing zone (not shown) and a outlet for the drawing of acid gas stream GS in the top region of the regenerator.
  • the regeneration zone is regarded as the region of the regenerator with which the laden absorbent comes into contact with the steam which is produced by the reboiler.
  • the regeneration zone preferably comprises internals, preferably random packings, structured packings and/or trays.
  • the regeneration zone is preferably divided into two to four packing sections arranged one on top of another that are separated from one another by bearing and holding trays and/or a distributor tray.
  • the height of the random packings/struc- tured packings in the regeneration zone is preferably in the range from 5 to 15 m, more preferably in the range from 6 to 12 m and most preferably in the range from 8 to 12 m.
  • the number of trays in the regeneration zone is preferably in the range from 10 to 30, more preferably 15 to 25 and most preferably 17 to 23 trays.
  • the feed inlet for the laden absorbent A2 is preferably above or in the upper region of the regeneration zone.
  • the regenerator in figures 1 and 2 additionally comprises an reboiler HE-R .
  • the reboiler is preferably a kettle-type reboiler, a natural circulation evaporator or a forced circulation evaporator.
  • the reboiler HE-R is preferably connected to a liquid draw at the bottom of the regenerator via a pipeline to introduce absorbent stream AS1 to the reboiler HE-R.
  • the bottom generally refers to the region beneath the regeneration zone.
  • the absorbent stream AS2 which usually is a vapor-liquid mixture generated in the reboiler, is preferably introduced into the lower region of the regenerator via a feed point above the liquid draw at the bottom but below the regeneration zone.
  • the bottom of the regenerator is divided by a collecting tray (not shown).
  • the absorbent collected therein is supplied to the crossflow heat exchanger HE-CF.
  • Stream AS2 is preferably recycled to the regenerator beneath the collecting tray.
  • the regenerator in all figures preferably comprises a draw point for the gaseous stream GS formed in the regeneration.
  • the draw point for the gaseous stream GS formed in the regeneration is preferably disposed in the top region of the regenerator.
  • the regenerator in the figures preferably comprises a rescrubbing zone (not show) having internals.
  • the internals present in the rescrubbing zone are preferably structured packings or random packings, where the packing height (random packings/structured packings) is preferably in the range from 1 to 10 m, more preferably 2 to 8 and most preferably in the range from 3 to 6 m.
  • the internals present in the rescrubbing zone are trays. More particularly, the number of trays is preferably in the range of 3 to 20, more preferably 4 to 16 and is preferably 6 to 12.
  • the trays in the scrubbing section may for example be valve trays, bubble-cap trays, Thormann trays or sieve trays.
  • scrubbing liquid there may be a separate feed for scrubbing liquid above or in the upper region of the rescrubbing zone (not shown). If scrubbing liquid, such as freshwater, is additionally supplied, it is preferable to guide this scrubbing liquid into the regenerator together with the condensate from an additional condensation step at the top of the regenerator.
  • the draw point for the gaseous stream GS formed in the regenerator is connected to a top condenser (not shown).
  • the top condenser preferably comprises a heat exchanger, a vessel for phase separation (phase separation vessel), a gas draw and a condensate outlet.
  • Condensers used may, for example, be condensers having cooling coils or helical tubes, jacketed tube condensers and shell and tube heat exchangers.
  • the embodiments shown in figures 1 to 4 comprise two heat pumps HP1 and HP2 in serieswhich are configured to transfer thermal energy from heat stream HS1, preferably fluid stream FS1, to the regeneration step c).
  • heat stream HS1 and heat transfer material stream HTMS1 are fed to heat exchanger HE1, which is preferably an indirect gas-to-liquid heat exchanger, to obtain a heat stream HS2 having a reduced thermal energy compared to heat stream HS1 and a heat transfer material stream HTMS2 having a higher thermal energy compared to heat transfer material stream HTMS1 .
  • heat stream HS1 is fluid stream FS1
  • heat stream HS2 is fluid stream FS2.
  • heat exchanger HE1 is configured to receive cooling medium stream CMS2 instead of heat stream HS1.
  • heat exchanger HE1 is preferably an indirect heat exchanger and more preferably an evaporator.
  • the outlet of heat exchanger HE1 is configured to confer heat transfer material stream HTMS2 to a compressor, preferably a rotary screw compressor, a centrifugal compressor, a piston compressor or an axial flow compressor, where heat transfer material stream HTMS2 is compressed to obtain a heat transfer material stream HTMS3 which is preferably connected to the inlet of heat exchanger HE2 via a pipeline.
  • a compressor preferably a rotary screw compressor, a centrifugal compressor, a piston compressor or an axial flow compressor
  • heat transfer material stream HTMS2 is compressed to obtain a heat transfer material stream HTMS3 which is preferably connected to the inlet of heat exchanger HE2 via a pipeline.
  • heat exchanger HE2 thermal energy from heat transfer material stream HTMS3 from heat pump HP1 is transferred to a second heat transfer material stream HTMS1 of heat pump HP2.
  • Heat exchanger HE2 is preferably an indirect heat exchanger
  • Heat exchanger HE2 comprises an additional outlet for the second heat transfer material stream SHTMS2 which is preferably transferred to a second compressor, preferably a rotary screw compressor, a centrifugal compressor or an axial flow compressor, via a pipeline to obtain a second heat transfer material SHTMS3.
  • the outlet of the compressor for the second heat transfer material stream SHTMS3 is preferably connected to the inlet of heat exchanger HE-R, which is configured to be the reboiler for the regenerator.
  • thermal energy is transferred from the second heat transfer material stream SHTM3 to an absorbent stream AS1 to obtain an absorbent stream AS2 having a higher thermal energy compared to absorbent stream AS1 and to obtain a second heat transfer material stream SHTMS4 having a reduced thermal energy compared to the second heat transfer material stream SHTMS3.
  • the outlet for absorbent stream AS2 of heat exchanger HE-R is preferably connected to an inlet beneath the regeneration zone of the regenerator.
  • the heat pump HP1 comprises the heat exchanger HE1, the heat exchanger HE2 and the compressor connected to heat exchangers HE1 and HE2.
  • the heat pump H2 comprises the heat exchanger HE2, the heat exchanger HE-C and the compressor connected to heat exchangers HE2 and HE-C.
  • Heat pumps HP1 and HP2 are connected in series, meaning that heat exchanger HE2 is the condenser for heat transfer material HTM1 of heat pump HP1 while at the same time being the evaporator for heat transfer material HTM2 of heat pump HP2.
  • Figures 1 to 3 additionally show heat pumps HP1 and HP2 which additionally comprise optional equipment configured to perform the optional recycling steps R1 and R2.
  • This additional equipment comprises a means for expanding the respective heat transfer material streams HTMS4 and SHTMS4 to obtain the respective heat transfer material streams HTMS5 and SHTMS5, which preferably have the same temperature and pressure as respective heat transfer material streams HTMS1 and SHTMS1, so they can be recycled to the inlet of respective heat exchanger HE1 and HE2.
  • the means for expanding the respective heat transfer material streams is preferably a thermal expansion valve.
  • FIG. 4 shows serial heat pumps HP1 and HP2 in which heat pump HP2 is operated as an open-loop heat pump which is not configured to include the recycling step R2. This embodiment is particularly preferable if heat transfer material HTM2 of heat pump HP is water.
  • the apparatuses represented in figures 1 to 4 can be operated according to the process conditions described in the first aspect of this invention.
  • the invention is directed to the use according to Claim 18.
  • the examples are based on calculations performed using a simulation model.
  • the phase equilibria were described using a model by Pitzer (K. S. Pitzer, Activity Coefficients in Electrolyte Solutions 2nd ed., CRC Press, 1991, Chapter 3, Ion Interaction Approach: Theory).
  • the simulation of the absorption processes is described by means of a mass transfer-based approach; details of this are given in Asprion (Asprion, N.: Nonequilibrium Rate-Based Simulation of Reactive Systems: Simulation Model, Heat Transfer, and Influence of Film Discretization, Ind. Eng. Chem. Res. (2006) 45 (6), 2054-2069).
  • Example 1 is based on calculations performed using a simulation model.
  • the phase equilibria for the carbon capture part were described using a model by Pitzer (K. S. Pitzer, Activity Coefficients in Electrolyte Solutions 2nd ed., CRC Press, 1991, Chapter 3, Ion Interaction Approach: Theory).
  • the simulation of the absorption processes is described by means of a mass transfer-based approach; details of this are given in Asprion (Asprion, N.: Nonequilibrium Rate- Based Simulation of Reactive Systems: Simulation Model, Heat Transfer, and Influence of Film Discretization, Ind. Eng. Chem. Res. (2006) 45 (6), 2054-2069).
  • thermodynamic data are provided by PC-SAFT (NH3), (Gross, J.; Sadowksi, G.: Industrial & engineering chemistry research, 2002, 41 (22) 5510) and for water by NBS tables (NBS/NCR Steam Tables by L. Haar, et al., New York: Hemisphere Publishing, 1984), respectively.
  • Example 1 is based on the process scheme represented in Figure 4 in which heat is transferred from fluid stream FS1 to a series of heat pumps HP1 and HP2 via an intermediate cooling cycle comprising a direct contact cooler DCC and in which heat pump HP2 is configured as an open-loop heat pump, with minor variations as further described below.
  • a fluid stream FS1 of 1389 t/h having the composition depicted in Table A below and a temperature of 70°C and a pressure of 1 .01 bar is fed to the bottom of a heat exchanger HE-C which is configured as a direct contact cooler (DCC).
  • HE-C heat exchanger
  • FS1 is contacted in countercurrent flow with water as cooling medium stream CMS1 to obtain a fluid stream FS2 with a flow rate of 124.1 t/h at a temperature of 35°C and a pressure of 0.99 bar, which is slightly compressed to a pressure of 1 .07 bar and a temperature of 43.4°C before being introduced to the absorption step b).
  • CMS1 is introduced at the top of the HE-C with a flow rate of 3233.3 t/h at a temperature of 40°C and a pressure of 2.25 bar. Thermal energy is transferred from fluid stream FS1 to cooling medium stream CMS1 to obtain a cooling medium stream CMS2 at the bottom of HE-C. A small part of CMS2 (150.7 t/h) is purged from the process. 3275 t/h of CMS2 having a temperature of 61 ,4°C and a pressure of 1 .01 bar are used as a heat stream HS1 for a serial heat pump comprising a first heat pump HP1 with ammonia as heat transfer material HTM1 and a second heat pump HP2 with water as heat transfer material HTM2.
  • Heat pump HP1 is designed as a closed-loop heat pump including a regeneration step.
  • Heat pump HP2 is designed as an open-loop heat pump.
  • Thermal energy from heat stream HS1 (CMS2) is transferred through evaporator HE1 of heat pump HP1 to a heat transfer material stream HTMS1 having a flow rate of 408.19 t/h at a temperature of 37.7°C and a pressure of 14.54 bar to obtain a gaseous heat transfer material stream HTMS2 having a flow rate of 408.19 t/h and a temperature of 37.6°C and a pressure of 14.49 bar.
  • a cooled cooling medium stream CMS3 is obtained which is further cooled in an additional cooler to a temperature of 32°C and pumped with a pressure of 4.5 bar to heat exchanger HE-C.
  • Heat transfer material stream HTMS2 is compressed in a compressor obtain a heat transfer material stream HTMS3 at a pressure of 75.48 bar and a temperature of 197.6°C.
  • Heat transfer material stream HTMS3 is fed to a heat exchanger HE2, which is the condenser for heat pump HP1 and the evaporator for heat pump HP2 to obtain a cooled, liquid heat transfer material stream HTMS4 having a temperature of 109.6°C and a pressure of 75.43 bar.
  • heat transfer material stream HTMS4 is expanded to obtain a cooled heat transfer material stream HTMS5 having a temperature of 37.7°C at a pressure of 14.54 bar, which is partially liquid (246,8 t/h) and gaseous (161.4 t/h) and which is recycled has heat transfer material stream HTMS1 to heat exchanger HE1 .
  • thermal energy is transferred from heat transfer material stream HTMS3 to a second heat transfer material stream SHTMS1 having a flow rate of 174.3 t/h, a temperature of 99.6°C at a pressure of 5 bar to obtain a second heat transfer material stream SHTMS2 having a flow rate of 174.3 t/h at a pressure of 1 bar and a temperature of 99.6°C.
  • the second heat transfer material stream SHTMS2 is compressed in three stages, each stage comprising one compressor. In the first compressor, the pressure is increased to 1.5 bar and the temperature is increased to 146.1 °C.
  • a stream of additional water at a flow rate of 3.8 t/h and a temperature of 99.6°C and a pressure of 5 bar is added to obtain a second heat transfer material stream SHTSM3* having a temperature of 121.4°C at a pressure of 1.5 bar at a flow rate of 178.1 t/h.
  • the second heat transfer material stream STMS3* is further compressed to a pressure of 2.3 bar and a temperature of 134.1 °C.
  • Another stream of water having a temperature of 99.6°C and a pressure of 5 bar is added at a flow rate 5.8 t/h to obtain a second heat transfer material stream SHTM3** having a temperature of 134.1°C and a pressure of 2.3 bar at a flow rate of 183.9 t/h.
  • the second heat transfer material stream SHTMS** is still further compressed to obtain a second heat transfer material stream SHTMS*** with a pressure of 3.4 bar and a temperature of 184.3°C.
  • second heat transfer material stream SHTMS*** to obtain second heat transfer material stream SHTMS3 having a temperature of 147.8°C and a pressure of 3.4 bar and a flow rate of 190.0 t/h.
  • Thermal energy from second heat transfer material stream SHTMS3 is transferred to the reboiler of an absorber to maintain a temperature of 127.3°C at the bottom of the absorber.
  • a cooler second heat transfer material stream SHTMS4 is obtained having a temperature of 137.3°C and a pressure of 3.34 bar.
  • the coefficient of performance (COP) as a measure for the performance of the heat pump system is 2.34.
  • Heat pump HP2 is operated as an open-loop heat pump, i.e. , the second heat transfer material stream SHTMS4 was not recycled to heat exchanger HE2.
  • heat pump HP2 it would be possible to operate heat pump HP2 as a closed-loop heat pump and to recycle at least a part of the second heat transfer material stream SHTMS4 e.g., as stream SHTMS1 to the heat exchanger HE2 or to the compression step as additional streams of heat transfer material HTM2, eventually after adjusting the pressure and temperature by additional expansion, cooling or compression steps to adjust the properties of the stream HTMS4 to the respective input streams.
  • the example shows that the energy comprised in low temperature fluid stream FS1 can be effectively utilized to heat the regeneration step c).
  • Example 1 only that amount of steam is produced which is required in regeneration step c). Since the process of the invention produces steam, it can be supplemented by other steam sources, or it is possible to provide excess steam to other consumers. Alternatively, excess steam can be disseminated to the environment.

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Abstract

La présente invention concerne un procédé de production d'un écoulement fluidique désacidifié comprenant des pompes à chaleur connectées en série pour transférer de l'énergie d'une source de chaleur à l'étape de régénération. Selon un second aspect, l'invention concerne un appareil de production d'un écoulement fluidique désacidifié comprenant des pompes à chaleur connectées en série. Selon un troisième aspect, l'invention concerne l'utilisation de deux pompes à chaleur connectées en série pour transférer de l'énergie thermique d'une source de chaleur à l'étape de régénération dans un procédé de désacidification d'un écoulement fluidique.
PCT/EP2024/062549 2023-05-16 2024-05-07 Procédé de production d'un écoulement fluidique désacidifié, appareil de désacidification d'un écoulement fluidique et utilisation de pompes à chaleur pour désacidifier un écoulement fluidique Pending WO2024235739A1 (fr)

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CN202480032616.9A CN121127299A (zh) 2023-05-16 2024-05-07 用于生产脱酸流体流的方法、用于使流体流脱酸的设备以及热泵用于使流体流脱酸的用途
AU2024271426A AU2024271426A1 (en) 2023-05-16 2024-05-07 Method for producing a deacidified fluid stream, apparatus for deacidifying a fluid stream and use of heat pumps for deacidifying a fluid stream

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PCT/EP2024/062542 Pending WO2024235737A1 (fr) 2023-05-16 2024-05-07 Procédé de production d'un flux de fluide désacidifié et appareil de désacidification d'un flux de fluide
PCT/EP2024/062541 Pending WO2024235736A1 (fr) 2023-05-16 2024-05-07 Procédé de production d'un flux de fluide désacidifié, appareil de désacidification d'un flux de fluide et utilisation de pompes à chaleur pour désacidifier un flux de fluide
PCT/EP2024/062549 Pending WO2024235739A1 (fr) 2023-05-16 2024-05-07 Procédé de production d'un écoulement fluidique désacidifié, appareil de désacidification d'un écoulement fluidique et utilisation de pompes à chaleur pour désacidifier un écoulement fluidique

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PCT/EP2024/062542 Pending WO2024235737A1 (fr) 2023-05-16 2024-05-07 Procédé de production d'un flux de fluide désacidifié et appareil de désacidification d'un flux de fluide
PCT/EP2024/062541 Pending WO2024235736A1 (fr) 2023-05-16 2024-05-07 Procédé de production d'un flux de fluide désacidifié, appareil de désacidification d'un flux de fluide et utilisation de pompes à chaleur pour désacidifier un flux de fluide

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