Sulfur Recovery Plant Tail Gas Treatment Process
Field of the Invention
[0001] The present invention relates to a process for extracting sulfur from a gas
stream containing sulfur compounds and, more particularly, to a process for
desulfurizing the tail gas from a Claus unit
Background of the Invention
[0002] Sulfur-containing gas streams in petroleum refineries and natural gas plants
are typically desulfurized by the Claus process. The Claus process operates in two
major process steps. In the first, hydrogen sulfide is converted to elemental sulfur at
temperatures of approximately 1000°C by the combustion of approximately one-third of
the H2S in the gas stream to produce sulfur dioxide which then reacts with the remaining
H2S to produce elemental sulfur. Following condensation and removal of the molten
sulfur formed in this stage, the reaction between the H2S and the SO2 is continued in the
second, catalytic step in which elemental sulfur is produced at temperatures between
200-350°C over an alumina catalyst. The Claus reaction can be represented by the
equations:
H2S + 1.5 02^S02 + H20
2H2S + SO2 ^ 3S + 2H2O
[0003] As the second reaction is an equilibrium reaction which is favored at lower
temperatures, it is carried out in stages with condensation and removal of molten
elemental sulfur between each stage, followed by heating to the reaction temperature
for the next stage. Typically, there are three stages of catalytic conversions although
two stages are also conventional when a tail gas treatment unit is used. With the
progressive stagewise removal of the sulfur between stages, the temperature of each
stage is reduced to obtain the more favorable thermodynamic equilibrium: typically, the
first catalytic stage will be operated at a temperature from 315 to 330°C, the second at
about 240°C and the third, if used, at around 200°C with the outlet of each stage being
maintained at least 20°C above the dew point of the sulfur to avoid the generation of
liquid within the catalyst beds. Operation of the first stage at high temperature ensures
hydrolysis of a major portion of COS and CS2; operation of each bed close to the dew
point of the sulfur brings conversion closer to the equilibrium value.
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[0004] The Claus process has been improved over the years mainly by improvements
intended to reduce the residual sulfur levels in the tail gas. The basic Claus process will
generally produce an overall recovery of 95-97% sulfur but this is no longer considered
adequate in most instances, mainly for environmental reasons. The Jacobs
Comprimo™ SuperClaus*™^ process, using a special catalyst in the last reactor oxidizes
the H2S selectively to sulfur with air injected into the reactor to avoid formation of SO2,
has a sulfur efficiency of around 99.0%, depending on the composition of the Claus
feed.
[0005] The tail gas from the Claus unit contains residual quantities of sulfur in the
form of elemental sulfur, sulfur dioxide, hydrogen sulfide as well as other sulfurcontaining
compounds such as COS and CS2 which will need to be removed if the
highest degree of sulfur recovery is to be attained. In the United States, for example, a
minimum sulfur recovery efficiency of 99.8% is required for larger Sulfur Recovery Units
(SRUs), so that a tail gas treating unit is required.
[0006] Emissions from the Claus process may be reduced by: (1) extending the Claus
reaction into a lower temperature liquid phase, (2) adding a scrubbing process to the
Claus exhaust stream, or (3) incinerating the hydrogen sulfide gases to form sulfur
dioxide. Processes currently available that extend the Claus reaction into a lower
temperature liquid phase include Beavon Sulfur Recovery (BSR), BSR/Selectox,
Sulfreen, Cold Bed Absorption, Maxisulf, and IFP-1 processes. All of these processes
give higher overall sulfur recoveries of 98 to 99 percent when following downstream of a
typical 2- or 3-stage Claus sulfur recovery unit.
[0007] Sulfur emissions can also be reduced by adding a scrubber at the tail end of
the plant, these falling into one of two categories: oxidation tailgas scrubbers such as
the Wellman-Lord, Stauffer Aquaclaus, and IFP-2 processes, and reduction tailgas
scrubbers. In the reductive type of scrubbing process, sulfur in the tailgas is converted
to H2S by hydrogenation in a catalytic reduction step after which the cooled tailgas is
sent to a scrubber for H2S removal. Processes of this type include the Beavon and
SCOT (Shell Claus Off-gas Treating) processes with the SCOT process being the
current market leader in Claus tail gas treatment in spite the high capital requirement of
the SCOT process, approximately 30 to 50 percent of the cost of the Claus plant itself.
[0008] The Beavon process (BSR), described originally in U.S. Patent No. 3 752 877,
heats the Claus tail gas typically to 290-340°C by combustion of natural gas in an online
Reducing Gas Generator (RGG) for subsequent catalytic reduction of virtually all
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non-HaS sulfur components to H2S which is then removed by amine scrubbing.
Conversion of SO2 and elemental sulfur is by hydrogenation, while CO, COS and CS2
are hydrolyzed.
[0009] Various acid gas scrubbing processes are available for H2S removal. These
processes generally use an amine solution to remove the H2S and possibly other acid
gas contaminants by reaction with the amines, after which the amines are regenerated
in a separate column and the resulting H2S returned to the Claus plant feed. The
Cansolv process removes sulfur dioxide in a similar manner and recycles regenerated
sulfur dioxide to the Claus plant. Among the amine scrubbing processes is the highly
effective FLEXSORB™ process, originally developed by Exxon Research and
Engineering with its variants, the FLEXSORB SE™ and FLEXSORB SE Plus™
processes using proprietary severely hindered ethanolamine solvents which remove
H2S to levels which are fully compliant with current regulatory requirements.
[0010] In summary, therefore, the SuperClaus process is the market-leading
technology for 99.0-99.2% recovery. Currently the European Union BREF (Best
Available Technology Reference) guidance to refiners is 99.5% sulfur recovery and for
this intermediate recovery level, Lurgi's Sulfreen™ technology has been used. There is,
however, a significant likelihood that this guidance will be upgraded to a requirement in
coming years in view of current and pending legislation in various countries for enforcing
99.5% as a target sulfur recovery level. This exceeds the capabilities of the direct
oxidation technology while the cost of a reduction-absorption-recycle unit such as SCOT
for 99.5% recovery is prohibitively high. Longer term, it is expected that environmental
legislation will continue to drive up sulfur recovery requirements. For 99.9+% recovery,
ExxonMobil's FLEXSORB™ SE / SE Plus technology is the market leader. In the light
of these expectations, the Sulfreen process, like the SuperClaus technology, is likely to
become a regretted investment when the lower sulfur emissions / higher overall sulfur
recovery required by future regulation are enforced. Thus refiners face the possibility of
"regretted investment" should they choose a sulfur plant tail gas treating technology that
can meet current requirements but not easily be upgraded to meet future specifications.
[0011] We have now devised a process which utilizes the unique capabilities of the
sterically hindered aminoethoxyether sorbents to eliminate the reduction step in the
SCOT and similar processes. The resulting process can more economically achieve the
intermediate target of 99.5% - 99.8% overall recovery and provide a phased-investment
strategy for subsequent upgrade to achieve higher recoveries while still maintaining
amine consumption in the scrubbing process at an acceptably low level.
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Summary of the Invention
[0012] According to the present invention, the tail gas stream from a Claus plant
which comprises mostly H2S and very little SO2 (less than 2000 vppm) is first cooled in a
quench column, suitably using water as a coolant, after which the SO2 is absorbed in a
circulating stream of a dilute, absorbent solution of a severely sterically hindered
aminoether alcohol from which the amine component can be reclaimed in a simple
thermal, ion exchange or other reclamation process in which any SO2 or CO based heat
stable salts are converted. The gas stream from the quench column may then be
treated in a conventional amine tail gas treating unit, preferably using one of the highly
hindered aminoethoxyether solvents. Acid gas from the regenerator of the scrubber is
recycled back to the front of the Claus unit for sulfur recovery. The overall sulfur
recovery for the process may be greater than 99.5% of inlet sulfur.
[0013] In comparison with the conventional BSR or SCOT tail gas units, the Reducing
Gas Generator (RGG), hydrogenation reactor and the waste heat boiler are eliminated
thereby reducing the investment cost of the process scheme so that an upgrade of an
existing SRU to 99.9+% sulfur recovery efficiency is a straightforward process
investment with a "no regrets" factor. In addition, the following operational advantages
are achieved:
(i) No caustic is used in the quench column as the hindered aminoether alcohol
is capable of removing SO2 with a purge stream from circulating wash being sent to the
thermal reclaimer for recovering the solvent. If MDEA solution is used in the top stage
of the BSR quench column or contact condenser, the MDEA will be neutralized by SO2
but cannot be thermally reclaimed. Hence, a caustic solution has been the customary
requirement.
(ii) The hindered aminoether alcohol solvents are highly stable and have been
shown to have very low reactivity with any elemental sulfur in the vapor stream whereas,
primary, secondary and tertiary amine solvents such as DIPA (di-isopropanol amine) or
MDEA (methyl-diethanolamine) react with the elemental sulfur to yield polymers that can
precipitate and reduce the treating capacity. The hindered aminoether alcohol solvents
can tolerate high levels of heat stable salts and still are not as corrosive as other
amines.
(iii) The absence of the Reducing Gas Generator eliminates the need for
burning fossil fuel to produce hydrogen and, together with the absence of the
exothermic hydrogenation reactor, reduces the heat flow to the quench column.
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(iv) The quench column (contact condenser) from an existing SCOT or BSR unit
may be retained, minimizing capital requirements for the new unit.
Drawings
[0014] in comparison with the conventional BSR or SCOT tail g The single figure of
the accompanying drawings is a simplified process flow diagram for the present tail gas
treatment' process.
Detailed Description
Tail Gas Treating Unit
[0015] The figure shows an illustrative configuration for the present tail gas treatment
process. The tail gas from the two-or three-stage Claus plant enters the unit through
line 10. At this point, in a conventional BSR or SCOT unit, the tail gas would be routed
to a reducing gas generator (RGG) in which hydrogen is produced by the substoichiometric
combustion of natural gas for catalytic reduction in a subsequent
hydrogenation reactor of virtually all non-H2S sulfur components. The passage of the
Claus tail gas through the RGG typically heats the gas to a temperature of 290-340°C.
Alternatively, a tailgas preheater can be used to heat the tailgas and a H2 stream is
added for the hydrogenation reactions. Conversion of SO2 and elemental sulfur in the
hydrogenation reactor is by hydrogenation, while CO, COS and CS2 are hydrolyzed to
CO2 and any CO which is produced would be converted to CO2 by the water gas shift
reaction. The heated gas mixture would then pass in the conventional unit to a waste
heat boiler in which the temperature would be reduced to a value in the approximately
range of 170°C to 185°C before entering the quench column or contact condenser.
[0016] In the present scheme, however, the tailgas feed preheater (or the
conventional Reducing Gas Generator, RGG), the hydrogenation reactor and the waste
heat boiler (WHB) are eliminated: the tail gases from the Claus unit typically at a
temperature of 130-150°C and preferably 130-140°C, pass directly to the foot of column
11 in which they are cooled in the two stages of the column to a temperature of
approximately 40-50°C. The cooling medium in the lower stage of column 11 (quench
column) is provided by means of a circulating water loop which passes cooling water in
countercurrent to the ascending stream of tail gas received directly from the Claus unit.
In this respect, the present column, using a plain water cooling wash, differs from the
conventional alkaline contact condenser in which a caustic solution is used in the lower
section to remove SO2 before the gases encounter the alkaline scrubber solution. A
purge stream of water 35 is removed at the outlet of the circulating pump 12 in the
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circulation loop and a water-cooled heat exchanger 13 for the water is provided in the
return leg 14 of the loop to cool the water to the required temperature, together with a
filter/strainer (not shown in the figure) to remove any particulates including elemental
sulfur.
[0017] The cooled gases pass upwards in the column through a chimney tray 15 into
the second stage of column 11 (wash column) in which they pass in countercurrent to a
dilute circulating absorbent solution of a severely hindered aminoether alcohol which
absorbs any SO2 that is present in the tail gas from the Claus unit and further cools the
gases. This solvent solution is collected from the bottom of the top section of the
column in chimney tray 15 and circulated by pump 16 in circulating loop 17. A
slipstream of the solution is withdrawn through line 18 at the outlet of pump 16 and sent
to a thermal reclaimer 36 which recovers the amine solvent on a continuous basis and
rejects any SO2 or CO based heat stable salts. A slip stream of lean solution from the
regenerator of the absorber section is continuously added to the loop through line 20 to
maintain the concentration of the aminoether alcohol in the circulating solution.
[0018] The contacting devices in the quench column and wash column may be trays,
random packing, structured packing or other contacting devices.
[0019] The gas stream from the overhead of wash column 11 passes out through line
22 to absorber column 24. The gas stream via line 22 enters at the bottom of absorber
column 24 and passes upwardly in countercurrent to a descending stream of
aminoether alcohol absorbent solution from regenerator 25 entering through branch line
26 which takes a majority of the regenerated solvent solution from regenerator 25 with
less going to the top of wash column 11 via line 20. This stream is maintained with a
higher concentration of the amine than the dilute stream in wash column 11. The
hydrogen sulfide in the gas stream is absorbed by the aminoether alcohol in the
absorbent solution which passes out from the bottom of column 24 via line 28 and
passes to regenerator 25 by way of heat exchanger 30 in which it is brought to the
required regeneration temperature by the returning solvent solution from the foot of
regenerator 25 in line 27. Regeneration of the aminoether alcohol in the absorbent
solution is preferably carried out by heating and stripping and more preferably heating
and stripping with steam. A reboiler 37 with steam heat is provided to regenerate the
solution to the desired residual H2S loading.
[0020] The acid gas from the regenerator, mainly H2S, is collected from overhead
receiver 31 and returned to the front of the Claus unit through line 32. The scrubbed
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gas stream from the overhead of absorber column 24 is passed through line 33 to
incinerator 34 and then vented through a stack.
[0021] The quench column in the lower portion of column 11 may be omitted so that
the gases from the Claus unit pass directly to a wash column in which a dilute solution
of the aminoether alcohol is circulated in countercurrent to the gas streeam; in this case,
the column may comprise only one packed bed over which circulation of the dilute
solution of the aminoether alcohol takes place. The dilute recirculating solution of the
aminoether alcohol acts as a quench media as well as a sorbent for the SO2 in the
tailgas. A slip stream of the dilute amine solution is purged to the reclaimer from the
circulation loop as noted above.
[0022] With or without the separate quench function, the present scheme enables
significant savings to be effected both in capital expenditures by the elimination of the
units normally licated between the end of the Claus unit and the first column (tailgas
feed preheater or RGG, hydrogenation reactor and waste heat boiler) as well as in the
direct operating costs for these units. At the same time, the consumption of amine in
the dilute wash solution is maintained at a low level even without the reduction of the
non-H2S gases in the Claus effluent: the gases entering the column contain only minor
amounts of SO2 and are still at a relatively high temperature, so minimizing the amount
of SO2 which dissolves in the quench and/or wash liquids and, in any event, the salts
resulting from reaction of the amine and the SO2 can be regenerated in the reclaimer to
form fresh sorbent.
Operation of Claus Unit
[0023] The Claus unit is operated so as to produce a tail gas which contains at the
most a minimal content of SO2, below about 2000 vppm and preferably below 1000
vppm. The other sulfur components of the tail gas stream from the unit will comprise
mainly H2S along with COS, CS2 and sulfur vapor from the last condenser. In order to
maintain the desired minimal SO2 content in the tail gas stream, the Claus unit is
operated "off-ratio", that is, with a ratio of H2S:S02 higher than the normal 2:1 to ensure
that the SO2 is consumed as far as feasible in the Claus reaction. This result may be
achieved either by reducing the combustion air to the burner of the initial thermal stage
or by passing a portion of Claus feed gas around the main burner. Residual H2S in the
tail gas is removed by the aminoether solvent and for this reason; slight excesses of this
gas will not prove troublesome although economic considerations (solvent usage in
removing H2S) will indicate that careful control of the Claus unit will be of benefit. The
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objective, however, is to ensure removal or nearly complete removal of the SO2 from the
tail gas. The acid gas mixture passing to the absorber column includes H2S, and may
optionally include other gases such as CO2, N2, argon, CH4, H2, CO, COS.
Ethanolamine Solvent
[0024] The unit is operated using an absorbent solution containing a severely
sterically hindered secondary aminoether alcohol as the solvent for the hydrogen
sulfide. The term "absorbent solution" as used here includes but is not limited to
solutions in which the amino compound is dissolved in a solvent selected from water or
a physical absorbent or mixtures of water and physical absorbents. The term "severely
sterically hindered" is used to mean that the nitrogen atom of the amino moiety is
attached to one or more bulky carbon groupings. Typically, the severely sterically
hindered aminoether alcohols have a degree of steric hindrance such that the
cumulative -Es value (Taft's steric hindrance constant) is greater than about 1.75 as
calculated from the values given for primary amines in Table V in D. F. DeTar, Journal
of Organic Chemistry, 45, 5174 (1980), to which reference is made for such values.
See, also. Tar et al, JACS 1976, 98 (15), 4567-4571. These alcohols may have either
acyclic or cyclic moieties attached to the nitrogen atom(s) of the aminoether alcohol.
[0025] Another way of determining whether a secondary amino compound is
"severely sterically hindered" is by measuring its 15N nuclear magnetic resonance
(NMR) chemical shift. By such measurements it has been found that the "ordinary
sterically hindered" secondary amino compounds have a 15N NMR chemical shift
greater than about 5+40 ppm, when a 90% by wt. amine solution in 10% by wt. D2O at
35°C is measured by a spectrometer using liquid (neat) ammonia at 25°C as a zero
reference value. For example, 2-(2-tertiarybutylamino) propoxyethanol, 3-
(tertiarybutylamino)-l-propanol, 2-(2-isopropylamino)-propoxyethanol and tertiarybutylaminoethoxyethanol
had measured 15N NMR chemical shift values of 5+74.3,
5+65.9, 6+65.7 and 5+60.5 ppm, respectively, whereas the ordinary sterically hindered
amine, secondarybutylaminoethoxyethanol and the non-sterically hindered amine,
n-butylaminoethoxyethanol had measured 15N NMR chemical shift values of .5+48.9
and 535.8 ppm, respectively. When the cumulative Es values (Taft's steric hindrance
constant) of these amines is plotted against the 15N NMR chemical shift values of the
amino compounds mentioned above, a straight line is observed. The amino compounds
analyzed as having an 15N NMR chemical shift values greater than 5+50 ppm under the
test conditions described above had a higher H2S selectively than those amino
compounds having an 15N NMR chemical shift less than 5+50 ppm. The tertiary amino
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compound used for comparison, methyldiethanolamine (MDEA), had a measured 15N
NMR chemical shift value of 5+27.4 ppm.
[0026] The general formula for the severely sterically hindered secondary aminoether
alcohols which may be used as solvents is;
R3 R4 R6
I I I
R2—C—NHi-C^j-f-0(CH^OH
Rl Rs
where:
Ri and R2 are independently selected from alkyl and hydroxyalkyi groups of 1-4
carbon atoms,
R3, R4, R5 and Re are independently selected from hydrogen or alkyl and
hydroxyalkyi groups of 1-4 carbon atoms, with the proviso that at least one of R4
or R5 bonded to the carbon atom which is directly bonded to the nitrogen atom is
an alkyl and hydroxyalkyi group of 1-4 carbon atoms when R3 is hydrogen,
X and y are each positive integers from 2 to 4 and
z is a positive integer from 1 to 4.
[0027] The preferred severely sterically hindered secondary aminoether alcohols
have the formula:
R3 R4 R6
R2-C-NHi-C^O~CH2CH-OH
Rl R5
where:
Rl ~ R2 ~ R3 ~ CH3; R4 = R5 = Re = H;
Rl = R2 = R3 = CH3; R4 = H or CH3; R5 = Re = H;
Ri = R2 = R3 = Re = CH3; R4 = R5 = H;
Ri = R2 = R3 = CH3CH2; R4 = R5 = Re = H; or
Ri 5i R2 5i R3 = H, CH3, CH3H2, R4 5i R5 7^ R6 = H or CH3;
and X = 2 or 3.
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[0028] The aminoether alcohol compound is preferably one or more of the following
compounds:
Tertiarybutylaminoethoxyethanol (TBEE),
2-(2-tertiarybutylamino)propoxyethanol,
tertiaryamylaminoethoxyethanol,
(1-methyl-1-ethylpropylamino)ethoxyethanol,
2-(2-isopropylamino) propoxyethanol.
[0029] These compounds and other severely hindered aminoether alcohols useful as
chemical solvents for hydrogen sulfide, are described more fully, together with methods
for their manufacture and use in the removal of hydrogen sulfide from gas streams are
described more fully in U.S. Patents Nos. 4 487 967; 4 471 138; 4 894 178; 4 405 585
and 4 665 234 to which reference is made for such descriptions. The severely
hindered aminoether alcohols may be used in combination with other materials such as
other amines preferably methyldiethanolamine, amino acids, salts, metal hydroxides;
aminoalkanes, physical sorbents such as the sulfones, e.g. Sulfolane for improved
solvent properties in the absorbent solution, as described in U.S. Patents Nos. 4 508
692; 4 618 481; 4 895 670; 4 961 873; 4 112 052; 4 405 581; 4 405 585; 4 618 481; 4
961 873; 4 892 674; 4 417 075; 4 405 578, to which reference is made for descriptions
of processes using these solvents.
[0030] The aminoether alcohols are characterized by their low volatility and high
solubility in water at selective H2S removal conditions, and most of the compounds are
also generally soluble in polar organic solvent systems which may or may not contain
water.
[0031] The absorbent solution used in the absorber section 23 ordinarily has a
concentration of aminoether compound of about 10 wt% to 55 wt% of the total solution,
and preferably 10 wt% to 45 wt%, depending primarily on the specific aminoether
alcohol employed and the solvent system utilized. If the solvent system is a mixture of
water and a physical absorbent, the typical effective amount of the physical absorbent
employed may vary from 10 wt% to 50 wt% of total solution, depending mainly on the
type of amino compound being utilized. The dependence of the concentration of
aminoether alcohol on the particular compound employed is significant because
increasing the concentration of the aminoether compound may reduce the basicity of
the absorbent solution, thereby adversely affecting its selectivity for H2S removal,
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particularly if the aminoether alcohol selected has a specific aqueous solubility limit
which will determine maximum concentration levels within the range given above. It is
important, therefore, that the proper concentration level appropriate for each particular
aminoether alcohol be maintained to ensure satisfactory results. The solution in the
wash column is more dilute, typically with the aminoether at about 0.5 wt% to 15 wt% of
the total solution, and preferably 1 wt% to 10 wt%, again depending primarily on the
specific aminoether alcohol employed. The requisite dilution is maintained by adding
water to loop 17 upstream of pump 16 to replace the water lost in the purge stream.
[0032] The concentration of the aminoether alcohol circulating in the coolant solution
in the upper stage of the quench column is not as great as in the absorber column since
the main objective here is to cool the gas stream. The concentration of the aminoethoxy
compound is selected so as to maintain the solution in the column at a slightly alkaline
condition (pH at least 8) to neutralize any SO2 slippage from the Claus unit. If the SO2
concentration in the tail gas is maintained at the recommended long term average level
of 1,000 ppm maximum, a concentration of about 0.5 wt% to 7 wt% and preferably 1
wt% to 4 wt% in the circulating coolant wash will be sufficient to remove trace amounts
of SO2. Control of the concentration is effected by adjustment of the make-up rate of
regenerated solvent entering through line 20.
[0033] The absorbent solution may include a variety of additives typically employed in
selective gas removal processes, e.g., antifoaming agents, anti-oxidants, corrosion
inhibitors, and the like. The amount of these additives will typically be in the range that
they are effective in the system in use.
[0034] The aminoether compounds used in the present process have a pKa value at
20°C greater than 8.6, preferably greater than about 9.5 and more preferably the pKa
value of the amino compound will range between about 9.5 and about 10.6. If the pKa is
less than 8.6 the reaction with H2S is decreased, whereas if the pKa of the amino
compound is much greater than about 10.6, an excessive amount of steam is required
to regenerate the solution. To ensure operational efficiency with minimal losses of the
amino compound, the amino compound should have a relatively low volatility and, in
general, the aikoxylated amino alcohols are selected to have volatilities such that their
boiling points are above 180°C (760 mm Hg) and generally above 200°C. and more
above 225X.
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Unit Operation
[0035] In a typical mode of operation, the absorption step is conducted by feeding the
gaseous stream from the quench column into the lower portion of the absorption column
while fresh absorbent solution is fed into the upper region of the column. The normally
gaseous mixture, freed largely from the H2S, emerges from the upper portion of the
column, and the loaded absorbent solution, which contains the selectively absorbed
H2S, leaves the column near or at its bottom. The inlet temperature of the absorbent
solution during the absorption step is preferably in the range of from about 20° to about
100°C, and more preferably from 35° to about 60°C. Pressures in the absorber may
vary widely; acceptable pressures are between 1 to 80 bara, preferably 1 to 20 bara,
although good results may be achieved by operating at significantly lower pressures
from 1.02 to 3 bara. The amount of absorbent solution and concentration required to be
circulated to obtain a given degree of H2S removal will depend on the chemical structure
and basicity of the amino compound and on the partial pressure of H2S in the feed gas.
Gas mixtures with low partial pressures will require more liquid under the same
absorption conditions than gases with higher partial pressures.
[0036] A typical procedure for the H2S removal phase contacts the gas stream with
the aqueous absorbent solution in a column containing a number of trays at a low
temperature, e.g., below 45°C and at a gas velocity of at least about 10 cm/sec.(based
on "active" or aerated tray surface). Depending on the operating pressure of the gas,
the tray column will typically have fewer than 24 contacting trays, with, e.g., 4-16 trays
typically employed. The Mass Transfer Equivalent volume of random packing ,
structured packing or other contacting devices maybe utilized to achieve the same
degree of H2S absorption.
[0037] After contacting the gaseous mixture, the absorbent solution becomes
saturated or partly saturated with H2S and is at least partly regenerated so that it may be
recycled back to the absorber. As with absorption, the regeneration may take place in a
single liquid phase. Regeneration or desorption of the acid gases from the absorbent
solution may be accomplished by conventional means such as pressure reduction of the
solution or increase of temperature to a point at which the absorbed H2S flashes off, or
by passing the solution into a vessel of similar construction to that used in the
absorption step, at the upper portion of the vessel, and passing an inert gas such as air
or nitrogen or, more preferably, steam, upwardly through the vessel. The temperature of
the solution during the regeneration step should be in the range from about 50° to about
170°C, and preferably from about 100° to 130°C, and the pressure of the solution during
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regeneration should range from about 1.05 to 3.1 bar abs., preferably 2-2.75 bar abs..
The absorbent solution, after being cleansed of at least a portion of the H2S gas, is then
recycled back to the absorbing vessel with a minority stream being taken to the upper
stage of the quench column to replenish losses in that stage of the process. Makeup
absorbent may be added as needed.
[0038] In the preferred regeneration technique, the HsS-rich solution is sent to the
regenerator where the absorbed components are stripped by the steam which is
generated by re-boiling the solution. Pressure in the stripper is usually 1.05 - 3.1 bar
abs. preferably 2-2.75 bar abs. and the temperature is typically in the range from about
50° to 170°C, preferably about 100 to 130°C. Stripper and flash temperatures will, of
course, depend on stripper pressure; thus at about 1 to 2 bar abs. stripper pressures,
the temperature will be about 100° to about 120°C during desorption. Heating of the
solution to be regenerated may suitably be effected by means of indirect heating with
low-pressure steam. It is also possible, however, to use direct injection steam.
[0039] The purge stream of dilute coolant solution removed from the circulation loop
of the upper stage of the quench column can be reclaimed in a simple, atmospheric
pressure thermal reclamation process after reaction with SO2 whereas other amines
such as MDEA require more vacuum treatment in a rather expensive unit to remove
heat stable salts formed by reaction with SO2 and CO2. The conditions in the thermal
reclaimer are in 90° to 170°C, preferably 130° to 150°C. This temperature is achieved
by heating with medium pressure steam. Measured volumes of caustic are added to
release the amine from the heat stable salt. The sodium salts thus produced are then
purged from the reclaimer periodically. The use of the separate circulation loop for the
combined coolant/solvent in the upper stage of the quench column enables the small
amounts of SO2 to be removed separately from the larger quantities of H2S in the
absorber column and precludes the accumulation of heat stable salts in the absorber
circuit which are not removed in the regeneration step. Alternately, other reclaiming
techniques, such as, ion exchange or dialysis may also be used.

Claims
1. A process for the removal of hydrogen sulfide from the tail gas stream
from a Claus plant which comprises H2S and less than 2000 vppm SO2 , which
comprises:
(i) contacting the tail gas stream with a circulating stream of a dilute,
absorbent solution of a severely sterically hindered aminoether alcohol to cool the gas
stream and remove SO2 from the gas stream.,
(ii) contacting the cooled gas stream the gas stream from step (i) with an
stronger absorbent solution of a severely sterically hindered aminoether alcohol to
remove H2S from the gas stream.
2. A process according to claim 1 in which the tail gas stream from the
Claus plant comprises less than 1000 vppm SO2.
3. A process according to claim 2 in which the tail gas stream from the
Claus plant is at a temperature of 130 to 150°C when contacting the circulating stream
of the absorbent solution.
4. A process according to claim 1 in which the tail gas stream from the
Claus plant is initially cooled by contact with a stream of water as a coolant prior to
contact with the circulating stream of the dilute absorbent solution.
5. A process according to claim 3 in which the tail gas stream from the
Claus plant is at a temperature of 130 to 140°C when entering step (i).
6. A process according to claim 1 in which the severely sterically hindered
aminoether alcohol of the absorbent solution is a secondary aminoether alcohol of the
formula:
R3 R4 R6
R2-C--NH-eC^O-CH2CH-OH
1 I
Ri R5
-15-
where:
Ri = R2 = R3 = CH3; R4 = R5 = Re = H;
Ri = R2 = R3= CH3; R4 = H or CH3; R5 = Re = H;
Ri = R2 = R3 = Re — CH3; R4 = R5 = H;
Ri = R2 = R3 = CH3CH2; R4 = R5 = Re = H; or
Ri # R2 ^ R3 = H, CH3, CH3H2; R4 ?4 R5 ?s R6 = H or CH3;
and X = 2 or 3.
7. A process according to claim 4 in which the severely sterically hindered
secondary aminoether alcohol of the absorbent solution comprises tertiary-butylaminoethoxyethanol,
2-(2-tertiarybutylamino)propoxyethanol, tertiaryamylaminoethoxyethanol,
(l-methyl-l-ethylpropylamino)ethoxyethanol or 2-(2-isopropylamino) propoxyethanol.
8. A process according to claim 1 in which the absorbent solution of step (i)
has a concentration of aminoether alcohol of about 0.5 wt% to 15 wt% of the total
solution.
9. A process according to claim 1 in which the absorbent solution of step (ii)
has a concentration of aminoether alcohol of about 10 wt% to 55 wt% of the total
solution.
10. A process according to claim 1 in which the inlet temperature of the
absorbent solution during the absorption of step (ii) is from 40° to 60°C. and the
pressure during the absorption of step (ii) is from 1.02 to 3 bara.
11. A process for the removal of hydrogen sulfide from a gas stream, which
comprises:
(i) subjecting the hydrogen sulfide-containing gas to the Claus reaction to
convert hydrogen sulfide to sulfur and form a tail gas stream comprising H2S and less
than 2000 vppm SO2,
(ii) cooling the tail gas stream by contact with a stream of water as a coolant,
(iii) contacting the gas stream from step (ii) with a circulating stream of a
dilute, absorbent solution of a severely sterically hindered aminoether alcohol to further
cool the gas stream and to remove SO2 from the gas stream.
- 1 6 -
(iv) contacting the cooled gas stream the gas stream from step (iii) with a
stronger absorbent solution of a severely sterically hindered aminoether alcohol to
remove H2S from the gas stream.
12. A process according to claim 11 in which the Ciaus process comprising
the reaction of H2S and SO2 is operated at a ratio of higher than 2:1 (H2S:S02) to
produce elemental sulfur and a tail gas stream comprising H2S and less than 2000
vppm SO2.
13. A process according to claim 12 in which the tail gas stream from the
Claus plant comprises less than 1000 vppm SO2.
14. A process according to claim 11 in which the tail gas stream from the
Claus plant is at a temperature of 130 to 150°C when entering step (ii).
15. A process according to claim 13 in which the gas stream from step (iii) is
at a temperature of 40 to 60°C when entering step (iv).
16. A process according to claim 11 in which the severely sterically hindered
secondary aminoether alcohol of the absorbent solution has the formula:
R3 R4 R6
I f I
R2-C-NHi-C^O~CH2CH—OH
Rl R5
where:
Ri ~ R2 ~ R3 ~ CH3; R4 = R5 = Re = H;
Ri = R2 = R3= CH3; R4 = H or CH3; R5 = Re = H;
Ri ~ R2 ~ R3 ~ Re ~ CH3; R4 = R5 = H;
R-) = R2 — R3 — CH3CH2I R4 — R5 — Re — Hj or
Ri ^ R2 ^ R3 = H, CH3, CH3H2; R4 ?i R5 9t R6 = H or CH3;
and X = 2 or 3.
17. A process according to claim 11 in which the severely sterically hindered
secondary aminoether alcohol of the absorbent solution comprises tertiary-butylaminoethoxyethanol,
2-(2-tertiarybutylamino)propoxyethanol, tertiaryamylaminoethoxyethanol,
(l-methyl-l-ethylpropylamino)ethoxyethanol or 2-(2-isopropylamino) propoxyethanol.
- I T -
IS. A process according to claim 11 in which the dilute absorbent solution of
step (iii) has a concentration of aminoether alcohol of about 0.5 wt% to 15 wt% of the
total solution and the stronger absorbent solution of step (iv) has a concentration of
aminoether alcohol of about 10 wt% to 55 wt% of the total solution.
19. A process according to claim 11 in which the inlet temperature of the
absorbent solution during the absorption of step (iii) is from 40° to 60°C and the
pressure during the absorption of step (iii) is from 1.02 to 3 bara
20. A process for the removal of hydrogen sulfide from a gas stream, which
comprises:
(i) subjecting the hydrogen sulfide-containing gas to the Claus reaction to
convert hydrogen sulfide to sulfur and form a tail gas stream comprising HjS and less
than 1000 vppm SO2 at a temperature of 130 to 150°C,
(ii) cooling the tail gas stream to a temperature of 40-60°C by countercurrent
direct contact with cooling water circulating in a quench column having a cooling water
circulation loop,
(iii) contacting the gas stream from step (ii) in countercurrent with a
circulating stream of a dilute, absorbent solution of a severely sterically hindered
secondary aminoether alcohol in a quench column having a circulation loop for the
dilute absorbent solution to further cool the gas stream and remove SO2 from the gas
stream, and separating the further cooled gas stream from the dilute absorbent solution,
(iv) contacting the separated, cooled gas stream from step (iii) in
countercurrent with a stronger circulating absorbent solution of a severely sterically
hindered secondary aminoether alcohol in an absorber column having a circulation loop
for the circulating absorbent solution to remove H2S from the gas stream by absorption
into the absorbent solution to form a purified gas stream and separating the purified gas
stream from the absorbent solution,
(v) regenerating the absorbent solution by steam stripping in a regeneration
zone.
21. A process according to claim 20 in which the stronger absorbent solution
of step (iv) has a concentration of aminoether alcohol of 10 wt% to 55 wt% of the total
solution and the dilute absorbent solution of step (iii) has a lower concentration of 0.5
wt% to 15 wt% of the total dilute solution.
-18-
22. A process according to claim 20 in which the dilute absorbent solution of
step (iii) has a pH of at least 8.
23. A process according to claim 20 in which the absorbent solution from
step (iv) is regenerated as in step (v) by steam stripping at a pressure from 0.5 to 3
bara.
24. A process according to claim 1, in which a purge stream of the dilute
absorbent solution of the severely sterically hindered secondary aminoether alcohol
from step (ii) is processed to recover the hindered amine.
25. A process according to claim 24, in which a purge stream of the dilute
absorbent solution of a severely sterically hindered secondary aminoether alcohol from
step (ii) is processed in a thermal reclaimer to recover the hindered amine.
26. A process according to claim 11, in which a purge stream of the dilute
absorbent solution of a severely sterically hindered secondary aminoether alcohol from
step (iii) is processed to recover the hindered amine.
27. A process according to claim 25, in which a purge stream of the dilute
absorbent solution of a severely sterically hindered secondary aminoether alcohol from
step (ii) is processed in a thermal reclaimer or in other reclaiming processes to recover
the hindered amine.
28. A process as according to claim 20, in which a purge stream of the dilute
absorbent solution of a severely sterically hindered secondary aminoether alcohol from
step (iii) is processed to recover the hindered amine.
29. A process according to claim 27, in which a purge stream of the dilute
absorbent solution of a severely sterically hindered secondary aminoether alcohol from
step (ii) is processed in a thermal reclaimer to recover the hindered amine.
30. A process for the removal of hydrogen sulfide from the tail gas stream
from a Claus plant which comprises:
(i) passing the tail gas stream from the Claus plant without the addition of
hydrogen into contact with a circulating stream of a dilute, absorbent solution of a
severely sterically hindered aminoether alcohol to cool the gas stream and to remove
SO2 from the gas stream, (ii) contacting the cooled gas stream from step (i) with a
stronger absorbent solution of a severely sterically hindered aminoether alcohol to
remove H2S from the gas stream.
-19-
31. A process according to claim 30 in which the tail gas stream from the
Claus plant comprises less than 1000 vppm SO2.
32. A process according to claim 30 in which the tail gas stream from the
Claus plant is at a temperature of 130 to 150°C when entering step (i).
33. A process according to claim 30 in which the tail gas stream from the
Claus plant is initially cooled by contact with a stream of water as a coolant prior to
contact with the circulating stream of the absorbent solution.
34. A process according to claim 30 in which the severely sterically hindered
secondary aminoether alcohol of the absorbent solution has the formula:
R3 R4 R6
R2-C--NH-eC^O~CH2CH-OH
Ri R5
where:
Ri = R2 = R3 = CH3I R4 = R5 = Re = H;
Ri = R2 = R3= CH3; R4 = H or CH3; R5 = Re = H;
Ri = R2 - R3 - Re ~ CH3; R4 = R5 = H;
Ri ~ R2 ~ R3 ~ CH3CH2I R4 — Rg — Re = Hj or
Ri ji R2 5^ R3 = H, CH3, CH3H2; R4 5* R5 54 R6 = H or CH3;
and X = 2 or 3.-