U.S. patent application number 13/687043 was filed with the patent office on 2013-06-06 for offshore gas separation process.
The applicant listed for this patent is Michel A. DAAGE, Richard A. DAVI, Robert A. FEDICH, Thomas F. PARKERTON, Michael SISKIN. Invention is credited to Michel A. DAAGE, Richard A. DAVI, Robert A. FEDICH, Thomas F. PARKERTON, Michael SISKIN.
Application Number | 20130142717 13/687043 |
Document ID | / |
Family ID | 47430066 |
Filed Date | 2013-06-06 |
United States Patent
Application |
20130142717 |
Kind Code |
A1 |
SISKIN; Michael ; et
al. |
June 6, 2013 |
OFFSHORE GAS SEPARATION PROCESS
Abstract
A process for the selective absorption of normally gaseous acid
components from hydrocarbon gas mixtures containing both the acidic
components and gaseous non-acidic components which is carried out
in a gas separation unit located at an offshore marine production
installation. The sorbent used in the process comprises a severely
sterically hindered amino ether. The process is capable of
selectively removing H.sub.2S from gas mixtures which also contain
CO.sub.2 in addition to the hydrocarbon components.
Inventors: |
SISKIN; Michael; (Westfield,
NJ) ; FEDICH; Robert A.; (Long Valley, NJ) ;
DAAGE; Michel A.; (Hellertown, PA) ; PARKERTON;
Thomas F.; (Cypress, TX) ; DAVI; Richard A.;
(Milford, NJ) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
SISKIN; Michael
FEDICH; Robert A.
DAAGE; Michel A.
PARKERTON; Thomas F.
DAVI; Richard A. |
Westfield
Long Valley
Hellertown
Cypress
Milford |
NJ
NJ
PA
TX
NJ |
US
US
US
US
US |
|
|
Family ID: |
47430066 |
Appl. No.: |
13/687043 |
Filed: |
November 28, 2012 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
|
61566216 |
Dec 2, 2011 |
|
|
|
Current U.S.
Class: |
423/228 ;
422/611; 423/210 |
Current CPC
Class: |
B01D 2252/2025 20130101;
B01D 2259/45 20130101; C10L 3/103 20130101; B01D 2252/20426
20130101; B01D 2252/2041 20130101; B01D 2256/24 20130101; B01D
2252/20484 20130101; B01D 53/1462 20130101; B01D 2257/504 20130101;
B01D 2252/502 20130101; B01D 2257/304 20130101; B01D 2252/20405
20130101; B01D 53/1493 20130101; B01D 53/1468 20130101 |
Class at
Publication: |
423/228 ;
422/611; 423/210 |
International
Class: |
C10L 3/10 20060101
C10L003/10 |
Claims
1. A marine offshore petroleum fluid production installation
including a cyclic amine absorption natural gas purification unit
for separating acidic gases from produced petroleum gas, the unit
comprising an absorption tower and a regeneration tower through
which an aqueous amine absorbent solution is circulated to absorb
acidic gases from the gas in the absorption tower and to desorb
acidic gases in the regeneration tower to produce a stream of
purified gas and at least one stream of acidic gas removed from the
gas, the aqueous amine absorbent solution comprises an aqueous
solution of a severely sterically hindered amino ether of the
formula: R.sup.1--NH--[CnH2n-O-]x-OY where R.sup.1 is a secondary
or tertiary alkyl group of 3 to 8 carbon atoms, Y is H or alkyl of
1 to 6 carbon atoms, n is a positive integer from 3 to 8 and x is a
positive integer from 3 to 6.
2. A marine offshore petroleum fluid production installation
according to claim 1 in which R.sup.1 is a branched secondary or
tertiary alkyl group of 3 to 9 carbon atoms.
3. A marine offshore petroleum fluid production installation
according to claim 2 in which R.sup.1 is tertiary butyl.
4. A marine offshore petroleum fluid production installation
according to claim 3 in which n is 2.
5. A marine offshore petroleum fluid production installation
according to claim 1 in which x is 3.
6. A marine offshore petroleum fluid production installation
according to claim 1 in which Y is H
7. A marine offshore petroleum fluid production installation
according to claim 6 in which the amino ether is tert-butylamino
ethoxyethoxyethanol.
8. A marine offshore petroleum fluid production installation
according to claim 1 in which Y is methyl.
9. A marine offshore petroleum fluid production installation
according to claim 1 in which the amino ether is tert-butylamino
methoxy-ethoxyethoxyethanol.
10. A marine offshore petroleum fluid production installation
according to claim 1 in which the absorbent solution also comprises
a diamino ether of the formula:
R.sup.1--NH--[C.sub.nH.sub.2n--O--].sub.x--NHR.sup.2 where R.sup.1,
n and x are as defined in claim 1 and R.sup.2, which may the same
or different to R.sup.1, is a secondary or tertiary alkyl group of
3 to 8 carbon atoms.
11. A marine offshore petroleum fluid production installation
according to claim 1 in which the absorbent solution also comprises
bis-(t-butylamino ethoxy)ethane.
12. A marine offshore petroleum fluid production installation
according to claim 11 in which the absorbent solution comprises
tert-butylamino methoxy-ethoxyethoxyethanol and bis-(t-butylamino
ethoxy)ethane.
13. A process for the selective absorption of normally gaseous
acidic components from hydrocarbon gas mixtures containing both the
acidic component and gaseous non-acidic components, which process
is carried out in a gas separation unit located at an offshore
marine petroleum fluid production installation in which an aqueous
amine absorbent solution is circulated in a cyclic amine absorption
natural gas purification unit to absorb acidic gases from the
hydrocarbon gas in an absorption tower and to desorb acidic gases
in a regeneration tower to produce a stream of purified hydrocarbon
gas and at least one stream of acidic gas removed from the
hydrocarbon gas, the aqueous amine absorbent solution being an
aqueous solution of a severely sterically hindered amino ether of
the formula: R.sup.1--NH--[C.sub.nH.sub.2n--O--].sub.x--OY where
R.sup.1, Y, n and x are as defined in claim 1.
14. A process according to claim 13 in which H.sub.2S is
selectively removed from a produced natural gas stream which
contains H.sub.2S and CO.sub.2.
15. A process according to claim 13 in which the amino ether
comprises tert-butylamino-ethoxyethoxy ethanol.
16. A process according to claim 13 in which the absorbent solution
also comprises a diamino ether of the formula:
R.sup.1--NH--[C.sub.nH.sub.2n--O--].sub.x--NHR.sup.2 where R.sup.1,
Y, n and x are as defined in claim 1 and R.sup.2 is as defined in
claim 10.
17. A process according to claim 16 in which the absorbent solution
also comprises bis-(t-butylaminoethoxy)ethane.
18. A process according to claim 17 in which the absorbent solution
comprises tert-butylamino methoxy-ethoxyethoxyethanol and
bis-(t-butylaminoethoxy)ethane.
19. A process for purifying a stream of natural gas produced at a
marine offshore petroleum fluid production installation including a
cyclic amine absorption natural gas purification unit for
separating acidic gases from produced natural gas, the unit
comprising an absorption tower and a regeneration tower through
which an aqueous amine absorbent solution is circulated to absorb
acidic gases from the natural gas in the absorption tower and to
desorb acidic gases in the regeneration tower to produce a stream
of purified gas and at least one stream of acidic gas removed from
the natural gas, the aqueous amine absorbent solution being an
aqueous solution of a hindered.
20. A process according to claim 19 which selectively absorbs
H.sub.2S from the natural gas.
21. A process according to claim 19 in which the amino ether
comprises tert-butylamino-ethoxyethoxy ethanol.
22. A process according to claim 19 in which the absorbent solution
also comprises a diamino ether of the formula:
R.sup.1--NH--[C.sub.nH.sub.2n--O--].sub.x--NHR.sup.2 where R.sup.1,
Y, n and x are as defined in claim 1 and R.sup.2 is as defined in
claim 1.
23. A process according to claim 22 in which R.sup.1 is tertiary
butyl, n is 2 and x is 3.
24. A process according to claim 22 in which the absorbent solution
also comprises bis-(t-butylaminoethoxy)ethane.
25. A process according to claim 22 in which the absorbent solution
comprises tert-butylamino methoxy-ethoxyethoxyethanol and
bis-(t-butylaminoethoxy)ethane.
Description
FIELD OF THE INVENTION
[0001] This invention relates to a process carried out on an
offshore petroleum production platform for removing acid gases from
gas produced at the platform. It also relates to the gas treatment
unit for carrying out the process.
BACKGROUND OF THE INVENTION
[0002] As reserves in onshore natural gas and petroleum fields have
decreased over time, production of these resources has moved
progressively offshore and recently into ever deeper waters.
Interest in natural gas production has increased as the utility of
this energy source in transport, electrical power generation and
other applications have increased in recent years with recognition
of the importance of reducing atmospheric carbon emissions. The
natural gas produced with petroleum liquids and the gas from a gas
field frequently contains carbon dioxide and sulfur in the form of
hydrogen sulfide, as well as other acid gases such as, CS.sub.2,
HCN, COS and sulfur derivatives of light hydrocarbons (mercaptans
etc). Hydrogen sulfide (H.sub.2S) is desirably separated to meet
pipeline specifications before the gas is sent ashore by underwater
pipeline in view of its corrosive action on pipeline steels.
Similarly, it is also desirable to remove the hydrogen sulfide from
gas which is stored or processed at a production facility which is
not linked to the shore by a pipeline. When H.sub.2S is dissolved
in water, it forms a weak acid which promotes pipeline corrosion
The most common types of corrosion where H.sub.2S is present
consist of pitting, blistering, embrittlement, fatigue, and
cracking. The severity of the corrosion due to H.sub.2S is
determined by factors such as oxygen and carbon dioxide (CO.sub.2)
levels, temperature, gas velocity, pH levels less than 6.5
(acidic), especially in he presence of salt water (conductive
electrolyte), internal/external stresses, concentration (parts per
million or partial pressure levels). The combination of CO.sub.2
and H.sub.2S is more corrosive than H.sub.2S alone, and can be
considered very corrosive when combined with even minute quantities
of oxygen and for this reason, removal of both CO.sub.2 and
H.sub.2S is considered desirable.
[0003] The removal of acid gases from the produced fluids on
offshore platforms and production rigs raises significant problems.
The main constraints for application on an offshore platform are
space and weight limitations. Installing a complex system with
numerous equipment and extensive utilities to support its operation
is against the trend in the offshore industry to pursue compact
facilities and to reduce manning levels for safety and logistic
reasons and operating costs. A number of different technologies are
available for consideration including, for example, chemical
absorption (amine), physical absorption, cryogenic distillation
(Ryan Holmes process), and membrane system separation. Of these,
amine separation is a highly developed technology with a number of
competing processes in hand using various amine sorbents such as
monoethanolamine (MEA), diethanolamine (DEA), methyldiethanolamine
(MDEA), diisopropylamine (DTPA), diglycolamine (DGA),
2-amino-2-methyl-1-propanol (AMP) and piperazine (PZ). Of these,
MEA, DEA, and MDEA are the ones most commonly used. The amine
purification process usually contacts the gas mixture in the form
of an aqueous solution of the amine in an absorber tower with the
aqueous amine solution contacting the acidic fluid
countercurrently. The liquid amine stream is then regenerated by
desorption of the sorbed gases in a separate tower with the
regenerated amine and the desorbed gases leaving the tower as
separate streams. The various gas purification processes which are
available are described, for example, in Gas Purification, Fifth
Ed., Kohl and Neilsen, Gulf Publishing Company, 1997, ISBN-13:
978-0-88415-220-0.
[0004] The treatment of acid gas mixtures containing CO.sub.2 and
H.sub.2S with amine solutions typically results in the simultaneous
removal of substantial amounts of both the CO.sub.2 and H.sub.2S.
It is often desirable, however, to treat acid gas mixtures
containing both CO.sub.2 and H.sub.2S so as to remove the H.sub.2S
selectively from the mixture, thereby minimizing removal of the
CO.sub.2. Selective removal of H.sub.2S results in a relatively
high H.sub.2S/CO.sub.2 ratio in the separated acid gas which
simplifies the conversion of H.sub.2S to elemental sulfur, e.g.,
using the Claus process. Although primary and secondary amines such
as MEA, DEA, DPA, and DGA absorb both H.sub.2S and CO.sub.2 gas,
they have not proven especially satisfactory for preferential
absorption of H.sub.2S. In aqueous solution, the amines undergo
reaction with CO.sub.2 to form carbamates. The tertiary amine,
MDEA, has a high degree of selectivity toward H.sub.2S absorption
over CO.sub.2 but the commercial usefulness of MDEA is limited
because of its restricted capacity.
[0005] An improvement in the basic amine process involves the use
of sterically hindered amines. U.S. Pat. No. 4,112,052 describes
the use of hindered amines for nearly complete removal of acid
gases such as CO.sub.2 and H.sub.2S. U.S. Pat. Nos. 4,405,581;
4,405,583; 4,405,585 and 4,471,138 disclose the use of severely
sterically hindered amine compounds for the selective removal of
H.sub.2S in the presence of CO.sub.2. Compared to aqueous MDEA,
severely sterically hindered amines lead to much higher selectivity
at high H.sub.2S loadings. Amines described in these patents
include BTEE (bis(tertiary-butylamino)-ethoxy-ethane synthesized
from tertiary-butylamine and bis-(2-chloroethoxy)-ethane as well as
EEETB (ethoxyethoxyethanol-tertiary-butylamine) synthesized from
tertiary-butylamine and chloroethoxyethoxyethanol). U.S. Pat. No.
4,894,178 indicates that a mixture of BTEE and EEETB is
particularly effective for the selective separation of H.sub.2S
from CO.sub.2. U.S. 2010/0037775 describes the preparation of
alkoxy-substituted etheramines as selective sorbents for separating
H.sub.2S from CO.sub.2 US 2009/0308248 describes a different class
of absorbents which are selective for H.sub.2S removal in the
presence of CO.sub.2, the hindered amino alkyl sulfonate, sulfate
and phosphonate salts, with the sulfonate and phosphonates being
the preferred species.
[0006] Regardless of the improved selectivities and sorption
capacities offered by those new materials, they have not achieved
general acceptance for use in offshore units, the reason being that
as regulations regarding toxicity and biodegradability of chemicals
that could potentially be spilled into the ocean have become more
severe, the potential number of acceptable absorbents has become
correspondingly more limited. Acid gas clean-up on off-shore
platforms has therefore come to require absorbents to be selected
for with lower toxicity and higher biodegradability.
SUMMARY OF THE INVENTION
[0007] We have now identified a class of absorbents which have high
selectivity for the removal of H.sub.2S in the presence of CO.sub.2
with very acceptable environmental properties permitting their use
in offshore installations such as natural gas production platforms.
According to the present invention, therefore, we provide a process
for the selective absorption of normally gaseous acid components
from gas mixtures containing both the acidic component and gaseous
non-acidic components, which process is carried out in a gas
separation unit located at an offshore marine installation. The
preferred asorbents used in the process comprise severely
sterically hindered amino ethers, including ether alcohols,
bis-(amino) ethers and alkoxy amino ethers; mixtures of the amino
ether compounds may be used. The process is capable of selectively
removing H.sub.2S from gas mixtures which also contain CO.sub.2 and
so makes it useful for treating natural gas from fields containing
both these acidic components.
[0008] The invention also provides a gas separation unit containing
a liquid absorbent comprising hindered amino ethers and ether
alcohols. Offshore petroleum fluids production installations having
a gas separation unit with one of these sorbents are also provided.
The separation unit includes a cyclic amine absorption natural gas
purification unit for separating acidic gases from produced
petroleum gas; this unit has an absorption tower and a regeneration
tower through which an aqueous amine absorbent solution is
circulated to absorb acidic gases from the gas in the absorption
tower and to desorb acidic gases in the regeneration tower. The
purified petroleum gas and at least one stream of acidic gas
removed from the gas are recovered as separate streams from the
regenerator.
DRAWINGS
[0009] The single FIGURE of the accompanying drawings is a graph
showing the biodegradability of several candidate compounds as
reported below.
DETAILED DESCRIPTION
General Processing Features
[0010] The acid gas sorbents used in the present gas separation
process are normally used in the form of aqueous solutions which
can be circulated in the normal type of continuous cyclic amine gas
purification unit mentioned briefly above, comprising essentially
an absorber tower in which the aqueous amine solution is contacted
in countercurrent flow with the incoming gas mixture. The liquid
amine stream is then passed to a regenerator in which the sorbed
gases are desorbed by a change in conditions, typically a reduction
of pressure or an increase in temperature in a separate tower
although stripping with another gas stream may also be utilized;
the regenerated sorbent solution and the desorbed gases leave the
regenerator tower as separate streams. The present amine sorbents
can be used in the same manner as conventional amine sorbents and
consequently, similar operating practices in the units containing
these sorbents can be followed.
[0011] The processed gas mixtures include H.sub.2S, and may
optionally include other acidic gases such as CO.sub.2, SO.sub.2,
COS, HCN, as well as non-acidic gases such as N.sub.2, CH.sub.4,
H.sub.2, CO, H.sub.2O, C.sub.2H.sub.4, NH.sub.3, and the like. High
selectivity for H.sub.2S absorption is favored for the present
purposes although less selective absorption is not excluded when
required by the feed gas or purification needs. If processing
conditions are adjusted non-selective removal of the acid gas
components from the non-acidic components may be achieved with
subsequent separation of the acidic gases one from another, e.g.,
separation of H.sub.2S from CO.sub.2, allowing the CO.sub.2 to be
re-injected for reservoir pressure maintenance.
[0012] The preferred absorbents used in the separation units are
the severely sterically hindered amino ethers, ether alcohols and
alkoxy amino ethers, with especial preference given to the amino
ether derivatives of triethylene glycol.
[0013] The hindered amine ethers are used in the form of aqueous
solutions, typically from about 0.1 to 5M concentration in order to
secure adequate loading; variations both within this range and
outside it may be made according to individual processing
requirements, e.g., concentration of gas species in total gas flow,
size of unit, etc. In most cases, the rich solution will have an
amine concentration of 0.05 to 2.5 M. Conditions in the separation
unit will be typical of those used in conventional amine gas
purification processes, for example, in temperature swing
operation, sorption temperatures are typically in the range of
30-50.degree. C., more usually 40-50.degree. C. and desorption
temperatures typically at 60 to 140.degree. C., e.g.,
100-125.degree. C. In pressure swing operation the sorption and
desorption pressures are usually set by the pressure of the
incoming feed stream and perhaps also by any requirement for the
product stream.
[0014] A typical procedure for the selective H.sub.2S removal phase
of the process comprises selectively absorbing H.sub.2S in
countercurrent contact of the gaseous mixture is described in US
2009/00308248 to which reference is made for this description.
Production Installations
[0015] The gas purification or separation unit is situated in a
marine, offshore location, typically on an offshore gas or crude
oil production platform. In the case of a platform producing from
an oilfield, the gas will be the natural hydrocarbon gases which
are co-produced with the crude oil and which are separated from the
oil on the platform to stabilize the liquid before transport either
by pipeline or by offloading onto a transfer vessel. Production
platforms may be fixed to the ocean floor as with the familiar and
conventional rigid (concrete or steel) leg platforms or the
concrete gravity base structures such as the Condeep platforms used
in locations usually no more than 200 m in depth although some
Condeep structures have been installed in about 350 m of water.
Fixed platforms of this type have usually provided adequate space
for processing equipment. In deeper water, for example, over 500 m
depth, fixed platforms are not economically feasible and floating
production, storage and offloading structures tethered to the
seabed in a manner that eliminates most vertical movement of the
structure, such as tension leg platforms, SPAR or Deep Draft
Caisson Vessels (DDCVs), are used at greater depths up to about
2,000 m with one currently placed in over 2400 m (Perdido SPAR in
the Gulf of Mexico in 2,438 meters of water). The gas processing
unit and related equipment will be installed on the structure of
whatever kind in a manner conformable to space and stability
requirements. The produced gases may be handled according to the
location with close offshore platforms discharging the purified
natural gas into the pipeline to shore and, when pipelining to
shore is not an option as in the deepwater locations, to the
related storage facilities either on the same platform or on
another nearby storage facility. CO.sub.2 is frequently re-injected
into the formation to improve recovery of the oil or gas and for
this purpose, the CO.sub.2 will be sent to the re-injection
compressor equipment. Separated H.sub.2 may be handled in the same
way or, if possible, treated in a Claus plant and the product
sulfur stored for later disposal. On far offshore installations not
linked to shore by pipeline, gas liquefaction facilities can be
provided to store the hydrocarbon gases as well as separated gases
pending transfer to a vessel for transport ashore.
Absorbents
[0016] One class of H.sub.2S selective absorbents which are
predicted to exhibit favorable environmental characteristics,
particularly aquatic toxicity, are the hindered amine
alkylsulfonate and alkylphosphonate salts which are described in US
2009/0308248, to which reference is made for a description of these
salts as well as of their synthesis and use in selective gas
separation processes. Briefly, the salts are generally represented
by the following formulae:
##STR00001##
in which R.sup.1, R.sup.2, R.sup.3 and R.sup.4 are the same or
different and selected from H, C.sub.1-C.sub.9 substituted or
unsubstituted straight or C.sub.3-C.sub.9 substituted or
unsubstituted branched chain alkyl, C.sub.3-C.sub.9 cycloalkyl,
C.sub.6-C.sub.9 aryl, alkylaryl, arylalkyl, C.sub.2-C.sub.9
straight or branched hydroxyalkyl, cycloalkyl and mixtures thereof
provided that both R.sup.1 and R.sup.2 are not hydrogen and, when n
is 2 or more, R.sup.3 and R.sup.4 on adjacent carbon or on carbons
separated by one or more carbons, can be a cycloalkyl or aryl ring
and, when the substituents are substituted, they are heteroatom
containing substituents, preferably an --NR.sup.5R.sup.6 group
wherein R.sup.5 and R.sup.6 are the same or different and are
selected from H, C.sub.1-C.sub.9 straight or C.sub.3-C.sub.9
branched chain alkyl, C.sub.3-C.sub.9 cycloalkyl, C.sub.6-C.sub.9
aryl, alkylaryl, arylalkyl, C.sub.2-C.sub.9 straight or branched
chain hydroxyalkyl, cycloalkyl, provided that R.sup.5 and R.sup.6
are not both H, and further, when R.sup.1 is H, and n is 2 or more,
R.sup.2 and R.sup.3 or R.sup.4 on the carbon at least one carbon
removed from the aminic nitrogen can form a ring; n is an integer
of 1 or more, preferably 1 to 4, more preferably 2 to 4; metal
cation is one or more monovalent, divalent or trivalent metal
cation(s) sufficient to satisfy the valence requirements of the
anion(s), for example, magnesium, barium, sodium, lithium,
potassium or calcium with preference for sodium and potassium.
Salts formed from divalent cations can be half- or full-salts.
[0017] R.sup.1 and R.sup.2(R.sup.1 and R.sup.2 are not both
hydrogen) are preferably selected from H, C.sub.4-C.sub.6 alkyl,
more preferably C.sub.4-C.sub.6 branched chain alkyl, most
preferably tertiary-butyl. R.sup.3 and R.sup.4 are normally H or
C.sub.2-C.sub.3 alkyl. The value of n is preferably from 1 to 4,
most preferably 2 or 3.
[0018] For optimal sorption of the acidic component(s) of the gas
mixture, it is necessary to use the salts, preferably the alkali
metal salts in order to maintain a reserve of alkalinity in the
sorbent solution: the free acids are relatively less effective.
[0019] The sulfonate and phosphonate salts may be synthesized by
the methods described in US 2009/0308248 to which reference is made
for a description of such methods.
[0020] The preferred absorbent materials for offshore use are the
severely sterically hindered amino ethers and amino alcohols of
polyalkyleneglycols, especially diethylene glycol and, more
preferably triethylene glycol. These have been shown to be
selective for absorption of H.sub.2S in the presence of CO.sub.2
and other acidic gases in mixtures with non-acidic gases. The
hindered amino derivatives of triethylene glycol have been found to
be particularly favorable from the environmental point of view.
These absorbents have been found to exhibit high selectivity for
H.sub.2S absorption in the presence of acidic gases such a CO.sub.2
and from non-acidic gases.
[0021] The preferred amino ethers for offshore application are
defined by the formula:
R1-NH--[CnH2n-O--].sub.x--OY
where R.sup.1 is a secondary or tertiary alkyl group of 3 to 8
carbon atoms, preferably a tertiary group of 4 to 8 carbon atoms, Y
is H or alkyl of 1 to 6 carbon atoms, n is a positive integer from
3 to 8 and x is a positive integer from 3 to 6. The preferred
R.sup.1 group is tertiary butyl and the most preferred amino ethers
are those derived from triethylene glycol (n is 2, x is 3). When Y
is H, the amino ether is an amino ether alcohol such as
tert-butylamino ethoxyethoxyethanol, derived from triethylene
glycol; when Y is alkyl, preferably methyl, the amino ether is an
alkoxy amino ether, with preference for tert-butylamino
methoxy-ethoxyethoxyethanol. The monoamino ethers may be used in
blends with diamino ethers in which the terminal OH group of the
ether alcohol or the terminal alkoxy group of the alkoxy amino
ether is replaced by a further hindered amino group as expressed in
the formula:
R.sup.1--NH--[C.sub.nH.sub.2n--O--]--NHR.sup.2
where R.sup.1, n and x are as defined above and R.sup.2, which may
the same or different to R.sup.1, is a secondary or tertiary alkyl
group of 3 to 8 carbon atoms. A preferred diamino ether of this
type is bis-(t-butylamino ethoxy)ethane which may conveniently be
used as a mixture of tert-butylamino methoxy-ethoxyethoxyethanol
and bis-(t-butylamino ethoxy)ethane.
[0022] Preferred examples of these amino ethers are disclosed in
U.S. Pat. Nos. 4,405,583; 4,405,585, 4,471,138, 4,894,178 and U.S.
Patent Publication 2010/0037775, to which reference is made for a
full description of these materials, their synthesis and their use
in selective acidic gas separation processes. Their disclosures are
summarized below for convenience.
[0023] U.S. Pat. No. 4,405,583: The hindered diamino ethers
disclosed in this patent are defined by the formula:
##STR00002##
where R.sup.1 and R.sup.8 are each C.sub.1 to C.sub.8 alkyl and
C.sub.2 to C.sub.8 hydroxyalkyl groups, R.sup.2, R.sup.3, R.sup.4,
R.sup.5, R.sup.6, and Rare each hydrogen, C.sub.1-C.sub.4 alkyl and
hydroxyalkyl groups, with certain provisos to define the adequately
hindered molecule and m, n, and p are integers from 2 to 4 and o is
zero or an integer from 1 to 10. A typical diamino ether of this
type is 1,2-bis(tert-butylaminoethoxy)ethane, a diamino derivative
of triethylene glycol.
[0024] U.S. Pat. No. 4,405,585: The hindered amino ether alcohols
disclosed in this patent are defined by the formula:
##STR00003##
where R.sup.1 is C.sub.1-C.sub.8 primary alkyl and primary
C.sub.2-C.sub.8 hydroxyalkyl, C.sub.3-C.sub.8 branched chain alkyl
and branched chain hydroxyalkyl and C.sub.3-C.sub.8 cycloalkyl and
hydroxycycloalkyl, R.sup.2, R.sup.3, R.sup.4 and R.sup.5 are each
hydrogen, C.sub.1-C.sub.4alkyl and C.sub.1-C.sub.4 hydroxyalkyl
radicals, with the proviso that when R.sup.1 is a primary alkyl or
hydroxyalkyl radical, both R.sup.2 and R.sup.3 bonded to the carbon
atom directly bonded to the nitrogen atom are alkyl or hydroxyalkyl
radicals and that when the carbon atom of R.sup.1 directly bonded
to the nitrogen atom is secondary at least one of R.sup.2 or
R.sup.3 bonded to the carbon atom directly bonded to the nitrogen
atom is an alkyl or hydroxyalkyl radical, x and y are each positive
integers from 2 to 4 and z is an integer from 1 to 4. Exemplary
compounds of this type include the amino ether alcohol
tert-butylaminoethoxyethanol, a derivative of diethylene
glycol.
[0025] U.S. Pat. No. 4,471,138: This patent discloses the
desirability of using a combination of a diamino ether with an
aminoether alcohol. The two compounds are represented by the
respective formulae:
##STR00004##
where x is an integer ranging from 2 to 6. This mixture can be
prepared in the novel one-step synthesis, by the catalytic tertiary
butylamination of a polyalkenyl ether glycol,
HO--(CH.sub.2CH.sub.2O).sub.x--CH.sub.2CH.sub.2--OH, or halo
alkoxyalkanol. For example, a mixture of
bis-(tert-butylaminoethoxy)ethane (BTEE) and
ethoxyethoxyethanol-tert-butylamine (EEETB) can be obtained by the
catalytic tertiary-butylamination of triethylene glycol. The
severely hindered amine mixture, e.g., BTEE/EEETB, in aqueous
solution can be used for the selective removal of H.sub.2S in the
presence of CO.sub.2 and for the removal of H.sub.2S from gaseous
streams in which H.sub.2S is the only acidic component, as is often
the case in refineries.
[0026] U.S. Pat. No. 4,894,178: A specific combination of diamino
ether and aminoalcohol represented by the respective formulae:
##STR00005##
with x being an integer ranging from 2 to 6 and the weight ratio of
the first amine to the second amine ranging from 0.43:1 to 2.3:1.
This mixture can be prepared in the one-step synthesis, by the
catalytic tertiary-butylamination of the corresponding polyalkenyl
ether glycol, for example, by the catalytic tertiary-butylamination
of triethylene glycol. This mixture is one of the preferred
absorbents for use in offshore gas processing.
[0027] US 2010/0037775: The reaction of a polyalkenyl ether glycol
with a hindered amine such as tert-butylamine is improved by the
use of an alkoxy-capped glycol. In the case of alkoxy DEG, the
capped glycol now precludes the formation of an unwanted cyclic
by-product, tert-butyl morpholine (TBM). A preferred capped glycol
is methoxy-triethylene glycol although the ethoxy-, propoxy- and
butoxy homologs may also be used. The reaction between monomethoxy
triethylene glycol and tert-butylamine is shown to produce MEEETB
almost exclusively, in .about.95% yield, eliminating the need for
extensive distillation to remove the product.
[0028] The amino ether compounds may be used in conjunction with
other related materials such as an amine salt as described in U.S.
Pat. No. 4,618,481. The severely sterically hindered amino compound
can be a secondary amino ether alcohol or a disecondary amino
ether. The amine salt can be the reaction product of the severely
sterically hindered amino compound, a tertiary amino compound such
as a tertiary alkanolamine or a triethanolamine, with a strong
acid, or a thermally decomposable salt of a strong acid, i.e.,
ammonium salt or a component capable of forming a strong acid.
[0029] Similarly, U.S. Pat. No. 4,892,674 discloses a process for
the selective removal of H.sub.2S from gaseous streams using an
absorbent composition comprising a non-hindered amine and an
additive of a severely-hindered amine salt and/or a
severely-hindered aminoacid. The amine salt is the reaction product
of an alkaline severely hindered amino compound and a strong acid
or a thermally decomposable salt of a strong acid, i.e., ammonium
salt.
Selectivity of Candidate Compounds
[0030] Three characteristics which are important in determining the
effectiveness of the amino compounds herein for H.sub.2S removal
are "selectivity", "loading" and "capacity". "Selectivity" is
defined as the mole ratio fraction of the H.sub.2S to the CO.sub.2
in the liquid (sorbent solution) phase to the mole ratio fraction
of the H.sub.2S to the CO.sub.2 in the gaseous phase. The higher
this fraction, the greater the selectivity of the absorbent
solution for the H.sub.2S in the gas mixture. "Loading" is the
concentration of the H.sub.2S and CO.sub.2 gases physically
dissolved and chemically combined in the absorbent solution
expressed in moles of gas per moles of the amine. The amino
compounds used in the present invention typically have a
"selectivity" of not substantially less than 10 at a "loading" of
0.1 moles, preferably, a "selectivity" of not substantially less
than 10 at a loading of 0.2 or more moles of H.sub.2S and CO.sub.2
per moles of the amino compound. "Capacity" is defined as the moles
of H.sub.2S loaded in the absorbent solution at the end of the
absorption step minus the moles of H.sub.2S loaded in the absorbent
solution at the end of the desorption step. High capacity enables
one to reduce the amount of amine solution to be circulated and use
less heat or steam during regeneration.
Selectivity=(H2S/CO2) in solution/(H2S/CO2) in feed gas
Loading=Moles H2S/Moles absorbent compound Capacity=Moles H2S
absorbed/Moles H2S after desorption Moles H2S absorbed
[0031] The selectivity of the preferred amino glycol derivatives is
demonstrated by comparison of the following absorbents:
EETB Ethoxyethanol-tert-butylamine
(tert-butylamino-ethoxy-ethanol)
MEETB Methoxyethoxyethanol-tert-butylamine
EEETB Ethoxyethoxyethanol-tert-butylamine
BEETB Butoxyethoxyethanol-tert-butylamine
MEEETB Methoxyethoxyethoxyethanol-tert-butylamine
[0032] TEGTB Triethylene glycol-t-butylamine
(t-butylaminoethoxyethoxyethanol)
Bis-SE Bis-(t-butylaminoethyl)ether
[0033] Bis-TEGTB Bis-(t-butylamino ethoxy)ethane
(bis-(t-butylamino)triethylene glycol)
Experimental Procedure
[0034] 1. Absorption tests were carried out at 35.degree. C. on
0.15 M aqueous solutions of absorbent using a gas mixture of
nitrogen:carbon dioxide:hydrogen sulfide of 89:10:1 for 2 hours.
[0035] 2. Desorption experiments were run at 85.degree. C. in
flowing nitrogen for 2 hours at the same flow rate as the test gas
mixture.
[0036] The results are shown in Table 1 below.
TABLE-US-00001 TABLE 1 SUMMARY OF ABSORPTION TESTING RESULTS
Molecular Loading Capacity Selectivity- Compound Weight Selectivity
(%) (%) Reabsorption EETB (U.S. Pat. No. 4,405,585) 161.24 15.4
16.3 60 13.3 Bis-SE (U.S. Pat. No. 4,405,583) 216.36 16.7 28.2 80
25.2 MEETB 175 56.01 21.57 67.4 59.6 EEETB 189.30 75.4 13.1 89.3
86.7 BEETB 217.35 90.2 16.8 92.5 197.6 MEEETB 219.32 64.4 24.2 98.4
69.7 TEGTB (32.2%): 205.26/ 128.2 45.4 82.6 231.2
[Bis-TEGTB](67.4%) 260.42 (U.S. Pat. No. 4,894,178)
TBA-NH--(CH.sub.2).sub.2--HN-TBA 172.31 26.2 9.8 46 20.2
Selectivity = (H.sub.2S/CO.sub.2) in solution / (H.sub.2S/CO.sub.2)
in feed gas Loading = Moles of H.sub.2S / Moles of Compound
Capacity = Moles of H 2 S absorbed by solution - Moles of H 2 S
after desorption from solution Moles of H 2 S absorbed by solution
##EQU00001##
[0037] As can be seen, the methoxy-, ethoxy- and butoxy-substituted
diethylene and triethylene glycol-t-butyl amines have higher
degrees of selectivity as compared to the EETB and its diamino
derivative (Bis-SE, bis-(t-butylaminoethyl)ether) and have at least
equivalent and in most cases superior capacity and superior
selectivity after regeneration than the EETB and the corresponding
diamino bis-SE.
Assessment of Health and Environmental Aspects of Candidate
Compounds
[0038] To assess the toxicity potential and environmental fate
properties of various selective absorbents, quantitative structure
activity relationships (QSARs) were applied together with
experimental confirmation of aquatic toxicity.
[0039] The chemical structures of candidate absorbents were run
through a series of computer models for comparative purposes.
Physical chemical properties (i.e., vapor pressure, water
solubility, and octanol/water partition coefficient) were estimated
using two models, EPISuite.sup.1 and SPARC.sup.2. Biodegradation
potential was determined using BIOWin, a subroutine of EPISuite.
.sup.1 EPI (Estimation Programs Interface) Suite.TM. is a
Windows-based suite of physical/chemical property and environmental
fate estimation programs developed by the EPA's Office of Pollution
Prevention Toxics and Syracuse Research Corporation (SRC)..sup.2
Scalable Processor Architecture, the RISC instruction set
architecture of Sun Microsystems
[0040] The four candidates in the evaluation were:
[0041] Candidate A EETB
[0042] Candidate B MEEETB
[0043] Candidate C TEGTB
[0044] Candidate D Bis-TEGTB
Biodegradation
[0045] Table 2 below compares physical chemical properties (VP, WS,
Log K.sub.ow) of the candidate substances. The octanol/water
partition coefficient (or Log K.sub.ow) of all candidate substances
indicates these substances would not be expected to pose a
bioaccumulation concern.
TABLE-US-00002 TABLE 2 Property Predictions of Absorbents Vapor
Water Compound Pressure (Pa) Solubility, mg/l Log Kow A EETB 0.77
miscible -0.06 B MEETB 1.22 miscible 0.37 C TEGTB 0.014 miscible
-0.33 D Bis-TEGTB 0.05 miscible 1.49
[0046] BIOWin.sup.3 model predictions for candidate absorbents
indicate that primary biodegradation (loss of parent compound) will
occur over the range of days to weeks, whereas, ultimate
biodegradation (mineralization to carbon dioxide) will occur over
the range of weeks to months. .sup.3 BioWin dynamic wastewater
treatment process modeling and simulation package of EnviroSim
Associates Ltd.
[0047] The biodegradation of the four candidates was tested by
Manometric Respirometry following OECD TG 301F [at 20.degree. C.]
with the results in Table 3 below and in the accompanying
FIGURE.
TABLE-US-00003 TABLE 3 Biodegradability DAY A B D Mix C, D* 0 0 0 0
0 1 0.05 0.00 0.00 0.81 2 0.00 0.20 0.61 1.56 3 0.00 0.30 0.61 1.56
4 0.00 0.60 0.70 1.52 5 0.00 1.02 0.62 1.55 6 0.00 1.54 0.54 1.75 7
0.06 2.09 0.37 2.35 8 1.68 3.00 0.07 3.01 9 3.34 3.81 0.00 3.17 10
0.47 1.89 0.00 3.79 11 0.56 3.82 0.69 6.09 12 0.76 4.04 0.63 7.51
13 0.91 4.70 0.00 8.67 14 1.04 5.70 0.77 10.49 15 1.16 6.03 0.85
11.70 16 1.33 6.56 1.12 12.91 17 1.51 7.14 1.34 13.31 18 1.56 7.65
1.77 13.54 19 1.58 9.52 1.68 13.60 20 1.71 7.55 1.71 13.60 21 1.89
7.55 1.67 13.60 22 2.00 7.55 1.67 14.77 23 1.95 7.55 1.67 14.77 24
2.00 7.55 1.67 14.77 25 2.06 7.55 1.67 14.99 26 2.06 7.55 1.67
16.51 27 2.06 7.55 1.67 17.17 28 2.06 7.55 1.67 17.34 Mix C, D:
Approx. 33% C, 65-67% D
[0048] The continued upward trend in the biodegradation of the
mixture of C and D indicates that degradative elimination from the
environment can be expected with increasing time.
Aquatic Toxicity
[0049] Aquatic toxicity predictions for fish, invertebrates
(Daphnia) and algae were made using ECOSAR, also a subroutine of
EPISuite that estimates aquatic toxicity and verified
experimentally. The commercial TOPKAT.RTM. .sup.4model was used to
estimate mammalian toxicity endpoints. .sup.4 Accelrys Discovery
Studio Predictive Toxicology tool, Discovery Studio TOPKAT.
[0050] The acute aquatic toxicity predictions in Table 4 indicate
absorbents A, B, E and F exhibit toxicity to at least one aquatic
organism in the 10-100 mg/l range. Fish appear to be consistently
less sensitive than daphnids or algae.
TABLE-US-00004 TABLE 4 Aquatic Toxicity Predictions of Absorbents
Fish 96-hour Daphnia 48-hour Algae 96-hour Code Compound LC50
(mg/l) LC50 (mg/l) EC50 (mg/l) A EETB 924 (225) 52.3 (31.6) 48.5 B
MEEETB 667 39.9 42.9 C TEGTB 1,752 95.7 80.8 D Bis-TEGTB 152 10.5
16.6 Note: values in brackets ( ) indicate experimental
results.
[0051] Aquatic toxicity was tested experimentally using the OECD TG
202--Daphnia sp. Acute Immobilisation Test The results are given
below in Table 5.
TABLE-US-00005 TABLE 5 Aquatic Toxicity Daphnia Daphnia Predicted,
Experimental, 48 hours, 48 hours, EC.sub.50 (mg/l) EC.sub.50 (mg/l)
Classification A 52.3 10 < EC.sub.50 < 100 Harmful to aquatic
organisms B 39.9 EC.sub.50 > 100 No classification D 10.5 10
< EC.sub.50 < 100 Harmful to aquatic organisms Mix C/D 31.7
10 < EC.sub.50 < 100 Harmful to aquatic organisms
[0052] The classification "Harmful to aquatic organisms" signifies
that the compounds in question may be used in the offshore
environment subject to mitigation, for example, secondary treatment
or dilution. None were deemed toxic, barring their use. Based on
biodegradability and aquatic toxicity predictions none of the
candidate substances are expected to require a negative
environmental label (e.g., the European dead fish/dead tree symbol)
although absorbent D appeared on the basis of the predictions to be
least preferred from an environmental perspective.
Mammalian Toxicity
[0053] The TOPKAT.RTM. predictions for mammalian toxicity endpoints
given in Table 6 indicate absorbents A, and C have a low potential
for acute toxicity in rats, while absorbents B and D show predicted
acute toxicity in the range of 1000 to 2000 mg/kg, which would put
them in the harmful category. Chronic toxicity in rats is reported
as the Lowest Observed Adverse Effect Level (LOAEL), which is the
lowest dose level, in weight of chemical to body weight units,
which is predicted to cause an adverse effect. The Ocular Irritancy
module computes the probability of a chemical structure being an
ocular irritant in the Draize test. All candidates are expected to
cause severe eye irritation. The Developmental Toxicity Potential
module of the TOPKAT package predicts that candidate A derived from
diethylene glycol is likely to be less favorable than the
triethylene glycol derivatives.
[0054] Carcinogenic potential is predicted using the NTP Rodent
Carcinogenicity Module in TOPKAT and comprises four statistically
significant quantitative structure-toxicity relationship models.
These models are derived from 366 uniform rodent carcinogenicity
studies conducted by the National Cancer Institute. Positive
results listed in Table 4 below indicate the potential for the
candidate to be carcinogenic or not carcinogenic in either rats or
mice. Results scored as indeterminate indicate insufficient
evidence to score either as positive or negative. The model also
predicts that none of the candidate absorbents are expected to be
skin sensitizers, nor are they expected to be mutagens.
TABLE-US-00006 TABLE 4 Mammalian Toxicity Predictions of Absorbents
Tox Endpoint A B C D Rat Oral LD.sub.50 (mg/kg) 2500 1900 3400 1000
Chronic LOAEL (mg/kg) 68.9 46.3 97 24.8 Skin Sensitization No No No
No Eye Irritation Severe Severe Severe Severe Develop Tox Potential
Yes No No No Ames Mutagenicity Negative Negative Negative Negative
Carcinogenic Potential Male Rat Indeterm. Positive Indeterm.
Positive Female Rat Negative Positive Negative Negative Male Mouse
Negative Negative Negative Negative Female Mouse Negative Positive
Negative Negative
* * * * *