WO1997033678A1 - A method for removing nitrogen oxides, sulfur oxides, and other acid gases from a gas stream - Google Patents
A method for removing nitrogen oxides, sulfur oxides, and other acid gases from a gas stream Download PDFInfo
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- WO1997033678A1 WO1997033678A1 PCT/DK1997/000105 DK9700105W WO9733678A1 WO 1997033678 A1 WO1997033678 A1 WO 1997033678A1 DK 9700105 W DK9700105 W DK 9700105W WO 9733678 A1 WO9733678 A1 WO 9733678A1
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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
- B01D53/02—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 adsorption, e.g. preparative gas chromatography
- B01D53/06—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 adsorption, e.g. preparative gas chromatography with moving adsorbents, e.g. rotating beds
- B01D53/10—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 adsorption, e.g. preparative gas chromatography with moving adsorbents, e.g. rotating beds with dispersed adsorbents
- B01D53/12—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 adsorption, e.g. preparative gas chromatography with moving adsorbents, e.g. rotating beds with dispersed adsorbents according to the "fluidised technique"
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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
- B01D53/02—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 adsorption, e.g. preparative gas chromatography
- B01D53/06—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 adsorption, e.g. preparative gas chromatography with moving adsorbents, e.g. rotating beds
- B01D53/10—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 adsorption, e.g. preparative gas chromatography with moving adsorbents, e.g. rotating beds with dispersed adsorbents
Definitions
- the present invention relates to a method for removing nitrogen oxides, sulfur oxides, and other acid gases from a gas stream in which an adsorption agent suitable for adsorbing nitrogen oxides, sulfur oxides, and other acidic gases is introduced and contacted with the gas stream in a reaction zone wherein the nitrogen oxides, sulfur oxides, and other acidic gases are adsorbed by the adsorption agent,
- the adsorption agent is at least partially withdrawn from the reaction zone with the gas stream as an entrained suspension and substantially removed from the gas stream in a separation zone
- the methods according to the present invention may be classified as dry methods with gas-solid contact and regeneration of the adsorption agent.
- nitrogen oxides and sulfur oxides are adsorbed on the sorbent beads and removed from the gas stream.
- the beads consist of a 840-2000 ⁇ m alumina carrier activated with alkali or alkaline-earth metal oxides.
- the adsorption can take place in a single or multiple stage fluid bed reactor.
- the sorbent particles having adsorbed the SO and NO . from the gas is transported to a fluid bed heater wherein the N0 > is liberated by raising the temperature of the sorbent particles above 532°C using air as heating media. Since both NO and N0 2 are seen to evolve in this first regeneration step, the overall reactions may be shown as:
- the NO- is thus stripped from the sorbent particles and carried away in the heating gas stream.
- the hot sorbent particles with the N0 X removed therefrom are transferred into a two stage moving bed regenerator where they are contacted with a suitable regenerant gas stream in the first stage and steam in the second stage.
- regeneration gases are mentioned H 2 , CO, H 2 -CO mixtures, H ? S, CH.,, CjH ⁇ , Natural gas, and the before mentioned gases mixed with CO; and/or H;0.
- gases mentioned are all gases that will result in the formation of H 2 S at regenerator process conditions, among these are COS and CS;.
- a Na S0 4 + b CH) c Na ; 0 • + d H . .S + e SO. ⁇ I CO;+ g H ? 0
- the regenerated sorbent particles are cooled in a fluid bed cooler and recirculated to the moving bed adsorber.
- the sorbent bead particles (840-2000 ⁇ m) are replaced with sorbent powder particles of the size 30-500 ⁇ m. In this process the adsorption is performed in an entrained suspension adsorber.
- the advantage of the ES-NOXSO process is found in the fact that the adsorption rate for the comparatively large NOXSO sorbent beads (1.23 mm) is diffusion controlled while the adsorption rate in the ES-NOXSO process is chemically controlled.
- Al NO and SO are removed from the gas in a process comprising the following steps: - introducing and suspending sorbent particles suitable for adsorbing NO and SO. and having a size in the range from about 140 mesh (105 ⁇ m) to about 70 mesh (210 ⁇ m) in the gas stream containing NO x and SO. to be removed;
- this process may be modified in the following way: sorbent particles of an average size in the range of about 30 ⁇ m to about 500 ⁇ m are used; and the stream of separated sorbent particles is fed to a sorbent particle splitter where it is divided into a first stream which is recirculated directly to the first NO . . and SO. adsorption step and a second stream which is directed to the multi-cyclone heating NO. removal step.
- the ES-NOXSO process compared to the NOXSO process, has the disadvantage that the relatively small sorbent particles are not easily distinguished from fly ash or other pulverous solids suspended in the gas stream, hence requiring an efficient particle removal both upstream and downstream of the adsorber to prevent accumulation of fly ash or other pulverous solids in the sorbent, and to prevent discharge of sorbent particles into the atmosphere.
- the SNAP Process The SNAP Process.
- SNAP Process A modification of the ES-NOXSO process, the so-called SNAP Process is disclosed by Leif Mortensen, SK Power Company, Copenhagen, Denmark, Stig Bue Lading, FLS ilj ⁇ a/s, Copenhagen, Denmark, and Mark C. Woods, NOXSO Corporation, Bethel Park, Pennsylvania in "Experiences from a 10 MWe Demonstration Project with an innovative SO and NO. Adsorption Process (SNAP)", EPRI DOE EPA 1995 SO, Control Symposium, Miami Florida, March 28-31 1995.
- the major components of the SNAP process accomplish the same basic operations as occur in the bead or powder based process according to the NOXSO/ES-NOXSO concept.
- the major components of the SNAP process are shown schematically in Figure 1.
- the major components of the SNAP process as shown in Figure 1 are described below.
- GSA Gas Suspension Adsorber
- the GSA reactor comprises a riser with suitably designed conical inlet, cyclones for primary gas-solid separation, and means for solid recirculation to the bottom of the riser. Flue gas enters the reactor through the conical inlet at the bottom, and contacts suspended sorbent which adsorbs SO ⁇ and NO..,.
- the GSA reactor design allows for high flue gas velocity (3-6 m/s) and gas-solid contact time of 2-3 seconds, at a relatively low pressure drop
- the sorbent entrained in the flue gas is separated in the cyclones and is partly recycled to the bottom of the reactor, partly fed to the regeneration unit. Fine sorbent particles entrained in the gas exiting the GSA cyclones are removed in a particulate control unit and returned to the process. Clean flue gas proceeds through a booster fan directly to the stack from where it is released into the atmosphere.
- Sorbent heater section represents the first stage of the sorbent regeneration system. A slip stream of loaded sorbent from the GSA cyclone recycle loop and sorbent collected in the particulate control unit are introduced into the heater.
- the first sorbent heater is a multi-stage fluidized bed where the sorbent is heated by indirect heat transfer from heat transfer coils immersed in the fluidized bed.
- the heat transfer medium inside the heating coils is Hi Tec heat transfer medium. In this heater the sorbent reaches a temperature around 300 ' C.
- the first heater is followed by a second heating step where the sorbent is heated by indirect heat transfer from heat transfer coils immersed in the fluidized bed.
- the heat transfer medium inside these heating coils is combustion off-gases from the NOx destruction unit and the auxiliary burner. In this heater the sorbent reaches a temperature around 620"C.
- the sorbent regenerator is a two-stage fluidized bed.
- the heated sorbent is contacted with a regeneration gas, which also serves as the fluidization medium.
- the sulfated sorbent reacts with regeneration gas, and sulfur is released as S0 2 and H 2 S .
- H 2 S remaining on the surface is stripped off with steam.
- Sodium sulfide, which may be formed during the regeneration, is also converted into H;S by steam hydrolysis.
- the paper describes that the regeneration can be adopted to use several types of regeneration gases, e.g. natural gas, hydrogen, fuel gas etc.
- Sorbent cooler section
- the sorbent cooler section represents the last stage of the sorbent regeneration system.
- the first sorbent cooler is a multi-stage fluidized bed where the sorbent is cooled by indirect heat transfer from heat transfer coils immersed in the fluidized bed.
- the heat transfer medium inside the coils is Hi Tec heat transfer medium.
- the sorbent reaches a temperature around 300°C.
- the heated Hi Tec heat transfer medium is from the cooler circulated to the heater, which ensures that the energy consumption in the heating process is minimized.
- the first cooler is followed by a second cooling step where the sorbent is cooled by indirect heat transfer from heat transfer coils immersed in the fluidized bed.
- the heat transfer medium inside these cooling coils is a water/glycol solution.
- the temperature of the sorbent after this final cooling step is m the range 100-300°C.
- the sulfur compounds from the regeneration step are fed to a Claus unit, where they are converted into elemental sulfur.
- the tail gas from the Claus process is passed through a burner to convert all remaining sulfur compounds into SO .
- the gas is then cooled and recycled to the flue gas stream entering the GSA.
- the problem to be solved according to the present invention is to provide an improved version of dry adsorption processes for removal of e.g. nitrogen oxides, sulfur oxides and other acid gases from a gas stream with regeneration and recirculation of the adsorption agent, such as e.g. the SNAP process.
- a manor drawback of these processes is the requirement for an efficient particulate control device upstream of the reaction zone m order to avoid contamination of the adsorption agent with fly ash or other particulates contained in the inlet gas.
- this problem is solved by a metnod for removing nitrogen oxides, sulfur oxides, and other acid gases from a gas stream containing fly ash and/or other solid materials in which
- an adsorption agent suitable for adsorbing nitrogen oxides, sulfur oxides, and other acidic gases is introduced and contacted with the gas stream in a reaction zone wherein the nitrogen oxides, sulfur oxides, and other acidic gases are adsorbed by the adsorption agent, - whereafter the adsorption agent is at least partially withdrawn from the reaction zone with the gas stream as an entrained suspension and substantially removed from the gas stream in a separation zone,
- the separation zone comprises a first electrostatic filter and optionally an additional filter arranged upstream of the first electrostatic filter.
- the adsorption agent separated in the separation zone is partly recycled to the reaction zone, and partly introduced into the regeneration zone.
- the separation zone comprises a first electrostatic filter as well as an additional filter, e.g. a system of one or more cyclones
- the solid material precipitated in the additional filter is preferably divided into two streams, where the first stream is recycled to the reaction zone, whereas the second stream is directed to the regeneration zone.
- the solid material precipitated in the first electrostatic filter is divided and recycled in the same way.
- the reaction zone may be accommodated in all types of adsorption reactors, including fluid bed reactors (e.g. dense bed, spouted bed etc.), moving bed reactors and entrained suspension adsorbers. In the last mentioned case pulverous adsorption agents are used.
- the reaction zone comprises gas-solid contact in an entrained suspension adsorber, but in some applications the reaction zone comprises a fluid bed or a moving bed. In such applications fines of the adsorption agent and fly ash are elutriated from the bed and carried with the gas as an entrained suspension. In these cases an additional particulate stream is withdrawn directly from the reaction zone, introduced into a regeneration zone, and returned to the reaction zone.
- fly ash and/or other solid materials contained in the gas stream introduced into the reaction zone are partially removed in a second filter arranged upstream of the reaction zone.
- partial removal of fly ash and/or other solid materials is used to designate removal to particulate concentrations in the outlet gas from said second filter of at least 100 such as at least 1 g/N ⁇ r and in particular in the range 1-10 g/Nm J .
- the second filter may be a member selected from the group consisting of cyclones, ceramic filters, bag filters, gravimetric settling filters, and electrostatic filters.
- fly ash and/or other solid materials contained in the exit gas stream from the first electrostatic filter for removal of the adsorption agent are removed in a third filter arranged downstream of the first electrostatic filter.
- the third filter may be a member selected from the group consisting of bag filters, ceramic filters, and electrostatic filters.
- the third filter is preferably an electrostatic filter arranged adjacent to the first electrostatic filter in a common housing.
- the first electrostatic filter is used for separation of the sorbent with respect to the sulfur content.
- the operation of the electrostatic filter is adjusted so that the particulate stream withdrawn from said first electrostatic filter has a substantially higher sulfur content than the particulate part of the incoming entrained suspension.
- the adsorption agent consists of particles having an average particle size within the range 20-200 ⁇ m, preferably within the range 40-80 ⁇ m consisting of:
- an alumina stabilizer selected from the group consisting of silica, lanthana, other rare earths, titania, zirconia, clay, alkaline earths and mixtures thereof in an amount from an effective amount up to about 30 mole-?;.
- the gamma alumina substrate has preferably a biraodal pore size distribution comprising micropores and macropores, the micropores having an average pore diameter d> in the range 30 - 400 Angstroms and the macropores having an average pore diameter d. in the range 80 - 3000 Angstroms.
- the adsorbed nitrogen oxides, sulfur oxides, and other acidic gases are substantially removed from the adsorption agent in the regeneration zone comprising the following steps: - a heating step;
- the reaction zone comprises an entrained suspension adsorber
- the heating step comprises heating of the adsorption agent in a fluidized bed heater to remove NO, and the main part of the other acidic gases from the adsorption agent, withdrawing the liberated gases and the adsorption agent from the fluidized bed heater
- - the reducing gas treatment step comprises contacting the exit adsorption agent from the heating step with a reducing gas in a fluidized bed reactor to remove and release SO, as a mixture of SO> and H 2 S, withdrawing the mixture of SO; and H ?
- the stripping step comprises contacting the exit adsorption agent from the reducing gas treatment step with water vapour in a fluidized bed to remove adsorbed H-S from the adsorption agent;
- the cooling step comprises cooling the exit adsorption agent from the stripping step in a fluidized bed cooler;
- the exit adsorption agent from the cooler is recycled to the reaction zone either directly or via an adsorption agent buffer tank.
- the heating step/cooling step is preferably carried out by indirect heat transfer from heating/cooling coils immersed in a fluidized bed.
- the reducing gas is used as fluidization medium in the fluidized bed reactor in the reducing gas treatment step.
- reaction temperature in the fluidized bed reactor in the reducing gas treatment step is within the range 200-700 °C, preferably 300-600 °C, and in particular 300-500 °C.
- the regeneration process is a crucial part of any regenerable adsorption process, that constitutes a major part of the operational costs in the heating of the adsorption agent to the regeneration temperature, and in the addition of reducing agent.
- the regeneration temperature is known to depend on the reducing agent. As a rule of thumb the regeneration temperature required for pure substances may be correlated to the spontaneous ignition temperature of the substance. For example, the regeneration temperature required for methane is in the range 620-640 °C, being close to the spontaneous ignition temperature of 632 °C.
- mixtures of gases in general decrease the temperature of regeneration compared to the regeneration temperature for the pure substances.
- the regeneration temperature for methane is in the range 620-640 °C
- the regeneration temperature for natural gas (containing approximately 90 % Methane) is in the range 560-580 °C. This may be due to a synergistic effect of the mixture.
- Natural gas may contain up to 10 ? ; non-combustibles. Such non-combustible compounds, viz. CO , H : 0, etc., may be responsible for synergetic effects, thus enhancing the regeneration significantly.
- the conditions in the reducing agent treatment step in the regeneration zone are able to convert sulfur- and nitrogen-containing compounds into H 2 S, SO. and N... The produced sulfur compounds may thus participate directly in a regular downstream Claus process, while nitrogen is a non- pollutant .
- regeneration with a mixture containing substantial amounts of H 2 0 and/or CO may exhibit the advantage of eliminating at least one downstream processing (stripping) step and thus reduce the capital and operational costs.
- Another problem to be solved by the present invention is to provide another improved version of the above mentioned dry adsorption processes with regeneration and recirculation of the adsorption agent.
- regeneration temperature as well as operational cost may be reduced by use of low grade fuel in the reducing agent treatment step.
- the present invention does also relate to a method for removing nitrogen oxides, sulfur oxides, and other acid gases from a gas stream, in particular according to any of claims 1-14, in which
- an adsorption agent suitable for adsorbing nitrogen oxides, sulfur oxides, and other acidic gases is introduced and contacted with the gas stream in a reaction zone wherein the nitrogen oxides, sulfur oxides and other acidic gases are adsorbed by the adsorption agent,
- the adsorption agent is at least partially withdrawn from the reaction zone with the gas stream as an entrained suspension and substantially removed from the gas stream in a separation zone
- the reducing agent used in the reducing gas treatment step is a low grade f el.
- the term "low grade fuel” is intended to designate fuels containing impurities in an amount necessitating further processing in order to provide a generally acceptable fuel, and/or having a low heating value.
- Low grade fuel is usually processed before it is used in other processes, due to the general necessity of using pollutant free fuels.
- pollutants are usually sulfur containing compounds, nitrogen containing compounds or non-combustibles, such as nitrogen, water vapour, sulfur oxides and carbon oxides.
- the following gases may i.a. be used according to the present invention:
- unprocessed, sulfur containing effluents from the following processes: coal gasification, coal liquefaction, oil shale processing, tar sands processing, petroleum processing, mineral processing, and geothermal energy utilization;
- the low grade fuel contain at least one non-combustible component, e.g. CO , H Draw0, SO , NO, NO , N, , 0 . , etc.
- the low grade fuel may contain non-combustible compounds in an amount up to 95, preferably up to 50, in particular up to 25 % by volume.
- the low grade fuel contains non-combustible compounds in an amount of at least 10, preferably at least 15, in particular at least 20 by volume.
- the low grade fuel is a waste fuel.
- the low grade fuel may in particular contain sulfur containing compounds, such as sulfides, mercaptans, thioethers, thioaldehydes, and thioketones.
- the low grade fuel may in particular also contain nitrogen containing compounds, such as ammonia, urea, urethanes, amines, amides, jmides, and CN-containing compounds as well as mixed sulfur and nitrogen containing compounds .
- the adsorption agent consists of particles having an average particle size within the range 20-200 ⁇ m, preferably within the range 40-80 ⁇ m consisting of: (a) a gamma alumina substrate having a surface area in the range 100-500 m /g and a pore volume in the range 0.3-0.8 ml/g,
- an alumina stabilizer selected from the group consisting of silica, lanthana, other rare earths, titania, zirconia, clay, alkaline earths and mixtures thereof in an amount from an effective amount up to about 30 mole-%.
- the gamma alumina substrate has a bimodal pore size distribution comprising micropores and macropores, the micropores having an average pore diameter d ; in the range 30 - 400 Angstroms, and the macropores having an average pore diameter d; in the range 80 - 3000 Angstroms .
- the adsorbed nitrogen oxides, sulfur oxides, and other acidic gases are substantially removed from the adsorption agent in the regeneration zone comprising the following steps: - a heating step;
- the reaction zone comprises an entrained suspension adsorber
- the heating step comprises heating of the adsorption agent in a fluidized bed heater to remove NO and the main part of the other acidic gases from the adsorption agent, withdrawing the liberated gases and the adsorption agent from the fluidized bed heater;
- the reducing gas treatment step comprises contacting the exit adsorption agent from the heating step with a reducing gas in a fluidized bed reactor to remove and release SOv as a mixture of SO and H : S, withdrawing the mixture of SO and H;S and the adsorption agent from the fluidized bed reactor;
- the stripping step comprises contacting the exit adsorption agent from the reducing gas treatment step with water vapour in a fluidized bed to remove adsorbed H 2 S from the adsorption agent;
- the cooling step comprises cooling the exit adsorption agent from the stripping step in a fluidized bed cooler.
- the adsorbed nitrogen oxides, sulfur oxides, and other acidic gases are substantially removed from the adsorption agent in the regeneration zone comprising the following steps:
- fig. 1 is a diagrammatic illustration of the SNAP process described in the introductory part of the description
- fig. 2 schematically illustrates a process according to the present invention for removal of nitrogen oxides, sulfur oxides and other acid gases from a gas stream
- fig. 3 shows a preferred embodiment of the above process having a particle stream withdrawn from the reaction zone and sent to the regeneration zone
- fig. 4 shows further details of the regeneration process, according to a preferred embodiment
- fig. 5 shows an example of an preferred embodiment that serves as a process diagram for example 4.
- the gas stream (10) is passed through a reaction zone (1) where nitrogen oxides, sulfur oxides and other acid gases are adsorbed on an adsorption agent.
- the adsorption agent is withdrawn from the reaction zone (1) with the gas stream as an entrained suspension (11) and substantially removed from the gas m a separation zone (2) consisting of a first electrostatic filter (4) and an optional filter (5) upstream of the first electrostatic filter (4) .
- Separated adsorption agent (13) is introduced into a regeneration zone (3) or may be partly recycled (14) to the reaction zone (1) .
- nitrogen oxides, sulfur oxides and other acid gases adsorbed on the adsorption agent are substantially removed from the adsorption agent and withdrawn from the regeneration zone (3) in a concentrated form (17) .
- Regenerated adsorption agent (15) is recycled to the reaction zone (1) .
- An optional second filter (6) may be placed upstream of the reaction zone (1) for partial removal of fly ash and/or other solid materials from the inlet gas stream (16) .
- the separation zone (2) may be further processed for the removal of fly ash and/or other solid materials in an optional third filter (7) before the exit gas stream (18) is discharged into the atmosphere.
- an electrostatic filter as the third filter (7), it will be possible to arrange the first electrostatic filter (4) and the third electrostatic filter (7) in the same housing creating a filter where adsorption agent containing particulate stream can be withdrawn from the one end of the filter, and an adsorption agent free particulate stream can be withdrawn from the other end of the filter.
- Figure 3 illustrates a process similar to the process illustrated in figure 2 with a stream of particles (19) withdrawn from the reaction zone (1) and sent to the regeneration zone (3) .
- Figure 4 illustrates a process similar to the process illustrated in figure 2 with a regeneration zone (3) consisting of
- an optional adsorption agent buffer tank (31) an optional adsorption agent buffer tank (31) .
- Figure 5 show a process diagram for a process according to the present invention, m which a flue gas from a power generation station containing SO , NOx and fly ash
- reaction zone (1) where nitrogen oxides, sulfur oxides, and other acid gases are adsorbed on an adsorption agent.
- the pulverous adsorption agent is withdrawn from the reaction zone (1) with the gas stream as an entrained suspension (11) and 26
- a separation zone (2) consisting of a first electrostatic filter (4) and a cyclone (5) upstream of the electrostatic filter.
- Separated adsorption agent (13) is partly introduced into a regeneration zone (3), and partly recycled (14) to the reaction zone (1) .
- the regeneration zone consists of
- the regeneration zone produces three outlet streams, -a stream (25) from the fluidized bed heater (20) containing NOx in a concentrated form,
- Regenerated adsorption agent (15) is recycled to the reaction zone (1) .
- the gas stream (12) from the separation zone (2) is further processed for the removal of fly ash and/or other solid materials in an electrostatic filter (7) before the exit gas stream (18) is discharged into the atmosphere. It will be possible to arrange the first electrostatic filter (4) and the third electrostatic filter (7) in the same housing creating a filter where adsorption agent containing particulate stream is withdrawn from the one end of the filter, and an adsorption agent free particulate stream (32) is withdrawn from the other end of the filter.
- Example 1 Sour water stripper off-gas from a refinery as the reducing agent in the SNAP.
- a slip stream from the process of petroleum refining is the sour water stripper off-gas. This stream has a composition approximately as follows: H 2 S 45% H 2 0 30%
- This gas with the above composition is a typical example of a low grade fuel that is not generally acceptable as a fuel.
- the mixture contains two combustible components (H S and NH 3 ) and a non combustible component (H O) .
- the sour water stripper off-gas is today burned in the flare.
- the sour water stripper off-gas can be used as the reducing agent used in the regeneration zone for the SNAP, thus lowering the operational cost for the reducing agent treatment step considerably, and simultaneously reducing the emission of sulfur-oxides and nitrogen oxides to the atmosphere from the refinery flare.
- Example 2 Combustible gas mixture from a refinery as the reducing agent in the SNAP.
- a by-product stream from the process of petroleum refining is a gas stream containing a mixture of hydrocarbon, hydrogen sulphide and hydrogen. This stream has a composition approximately as follows:
- This gas is a typical example of a low grade fuel due to the complex composition of the mixture and the high content of hydrogen sulfide.
- the gas mixture is today used in the refinery for heat generation.
- the above mentioned gas mixture can be used as the reducing agent used in the regeneration zone for the SNAP, thus lowering the operational cost for the reducing agent treatment step considerably.
- Example 3 Mixture of sour water stripper off-gas and a combustible gas mixture from a refinery as a reducing agent in the SNAP.
- a mixture of the sour water stripper off-gas mentioned in example 1 and the gas mixture mentioned in example 2 will contain a variety of hydrocarbon, hydrogen, hydrogen sulfide, ammonia and non-combustible water vapour and must thus be classified as a low grade fuel.
- This gas mixture can be used as the reducing agent used in the regeneration zone for the SNAP, thus lowering the operational cost for the reducing agent treatment step considerably.
- Example 4 Using an electrostatic filter in the separation of SNAP adsorption agent and fly ash.
- the process disclosed in this example corresponds to the diagram shown in figure 5.
- the flue gas contains
- the gas is led to the reaction zone (1) comprising a gas suspension adsorber (GSA) with a diameter of 2.8 m.
- GSA gas suspension adsorber
- the gas stream (11) here contains
- the flue gas enters the separation zone (2) that comprises a cyclone (5) and an electrostatic filter (4) .
- the two electrostatic filters (4) and (7) are placed in the same housing, and actually constitute one electrostatic filter containing two outlets for collected particles.
- the solid material collected (13) in the separation zone (2) corresponds to a total amount of 54995 kg/h, of which
- the adsorption agent is led to a fluidized bed heater (20) that is using air as the fluidizing medium (24) .
- the adsorption agent is heated indirectly to 600 'C, by which NOx is liberated into the fluidization gas in a concentration of 9 ⁇ and leaves the system through (25) .
- the hot adsorption agent is led to the reducing agent treatment step where it is treated in a fluidized bed reactor (21) with a diameter of 1.2 m with natural gas (26) 43 N ⁇ r/h in 45 minutes, and then led to the steam treatment step, where it is treated in a fluidized bed reactor (22) with a diameter of 0.6 m with steam (27) 7 NmVh for 10 minutes.
- the gas stream leaving the steam treatment and reducing agent treatment step is mixed (28) and contains 74.6 kg/h sulfur as H . .S and SO; in concentrations of 30' and 2", respectively.
- the adsorption agent is afterwards led to the fluid bed sorbent cooler (23) that is using air as a fluidizing medium (29) where it is indirectly cooled to 125"C.
- the gas leaving the sorbent cooler does not contain any pollutants and is discharged into the atmosphere.
- the cooled adsorption agent particles are recycled (15) to the reaction zone (1) via an adsorption agent buffer tank (31) .
Abstract
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AU20222/97A AU2022297A (en) | 1996-03-11 | 1997-03-11 | A method for removing nitrogen oxides, sulfur oxides, and other acid gases from a gas stream |
EP97908142A EP0888165A1 (en) | 1996-03-11 | 1997-03-11 | A method for removing nitrogen oxides, sulfur oxides, and other acid gases from a gas stream |
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- 1997-03-11 WO PCT/DK1997/000105 patent/WO1997033678A1/en not_active Application Discontinuation
- 1997-03-11 CA CA 2248679 patent/CA2248679A1/en not_active Abandoned
- 1997-03-11 AU AU20222/97A patent/AU2022297A/en not_active Abandoned
- 1997-03-11 EP EP97908142A patent/EP0888165A1/en not_active Withdrawn
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EP0105547A1 (en) * | 1982-09-25 | 1984-04-18 | Metallgesellschaft Ag | Process for separating noxious material from off-gases |
US4940569A (en) * | 1984-10-12 | 1990-07-10 | Noxso Corporation | Sorbent and processes for removing nitrogen oxides, sulfur oxides and hydrogen sulfide from gas streams |
EP0549891A1 (en) * | 1991-12-02 | 1993-07-07 | Noxso Corporation | Nitrogen oxides and sulfur oxides removal utilizing transport line adsorber |
EP0559253A2 (en) * | 1992-03-03 | 1993-09-08 | Metallgesellschaft Ag | Process for eliminating pollutants from combustion exhaust gases and fluidized bed reactor used therefor |
Cited By (15)
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EP1078675A3 (en) * | 1999-08-27 | 2002-06-26 | Praxair Technology, Inc. | Fluid separation process and separation system therefor |
EP1078675A2 (en) * | 1999-08-27 | 2001-02-28 | Praxair Technology, Inc. | Fluid separation process and separation system therefor |
WO2015094966A1 (en) * | 2013-12-18 | 2015-06-25 | Basf Corporation | Improved adsorption of acid gases |
CN105828910A (en) * | 2013-12-18 | 2016-08-03 | 巴斯夫公司 | Improved adsorption of acid gases |
US10458329B2 (en) | 2014-03-06 | 2019-10-29 | Uop Llc | System and process for recovering power and steam from regenerator flue gas |
US11891581B2 (en) | 2017-09-29 | 2024-02-06 | Marathon Petroleum Company Lp | Tower bottoms coke catching device |
US11920096B2 (en) | 2020-02-19 | 2024-03-05 | Marathon Petroleum Company Lp | Low sulfur fuel oil blends for paraffinic resid stability and associated methods |
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US11860069B2 (en) | 2021-02-25 | 2024-01-02 | Marathon Petroleum Company Lp | Methods and assemblies for determining and using standardized spectral responses for calibration of spectroscopic analyzers |
US11898109B2 (en) | 2021-02-25 | 2024-02-13 | Marathon Petroleum Company Lp | Assemblies and methods for enhancing control of hydrotreating and fluid catalytic cracking (FCC) processes using spectroscopic analyzers |
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Also Published As
Publication number | Publication date |
---|---|
EP0888165A1 (en) | 1999-01-07 |
CA2248679A1 (en) | 1997-09-18 |
AU2022297A (en) | 1997-10-01 |
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