U.S. patent number 3,702,541 [Application Number 04/781,845] was granted by the patent office on 1972-11-14 for low temperature method for removing condensable components from hydrocarbon gas.
This patent grant is currently assigned to Fish Engineering & Construction, Incorporated. Invention is credited to Jerry G. Gulsby, Bill R. Randall.
United States Patent |
3,702,541 |
Randall , et al. |
November 14, 1972 |
LOW TEMPERATURE METHOD FOR REMOVING CONDENSABLE COMPONENTS FROM
HYDROCARBON GAS
Abstract
A low temperature method is provided for removing condensable
components from an inlet hydrocarbon gas, such as natural gas
having a high proportion of methane. The system includes a
fractionating column to remove condensed components and a novel
reflux step which is arranged to condense additional condensable
components from the gas after passing the gas through the
fractionating column and to return the additional condensed
components back to the fractionating column as reflux. The system
utilizes expansion means in the form of a gas turbine which is
connected such that the energy generated by the turbine is used to
operate a compressor to recompress the gas after removal of certain
of the condensable components therefrom.
Inventors: |
Randall; Bill R. (Houston,
TX), Gulsby; Jerry G. (Houston, TX) |
Assignee: |
Fish Engineering &
Construction, Incorporated (Houston, TX)
|
Family
ID: |
25124139 |
Appl.
No.: |
04/781,845 |
Filed: |
December 6, 1968 |
Current U.S.
Class: |
62/622 |
Current CPC
Class: |
C07C
7/04 (20130101); F25J 3/0209 (20130101); F25J
3/0233 (20130101); C07C 7/04 (20130101); F25J
3/0238 (20130101); C07C 9/04 (20130101); F25J
2200/30 (20130101); F25J 2240/02 (20130101); F25J
2220/66 (20130101); F25J 2200/74 (20130101); F25J
2235/60 (20130101); F25J 2200/02 (20130101); F25J
2230/20 (20130101); F25J 2205/04 (20130101); F25J
2270/04 (20130101); F25J 2230/60 (20130101) |
Current International
Class: |
C07C
7/04 (20060101); C07C 7/00 (20060101); F25J
3/02 (20060101); F25j 003/02 (); F25j 003/06 () |
Field of
Search: |
;62/23,24,26,27,28,38,39,40,9,13,30,41 |
References Cited
[Referenced By]
U.S. Patent Documents
Primary Examiner: Yudkoff; Norman
Assistant Examiner: Purcell; A.
Claims
What is claimed is:
1. In a method for removing condensable components from a
hydrocarbon gas, the combination of steps comprising:
heat exchanging a turbine expanded fractionally distilled gas
stream, a cooled separated inlet gas stream, and an inlet gas
stream with turbine expanded fractionally distilled gas, thereby
condensing successively higher boiling components from said turbine
expanded fractionally distilled gas stream, cooled separated gas
stream and inlet gas stream;
separating said condensed components from said streams;
flowing said separated condensed components separately to said
fractional distillation column;
withdrawing a gaseous non-condensed portion from the cooled
separated inlet gas stream;
turbine expanding the withdrawn gas for flow to the column;
the turbine expander of the respective streams being mechanically
connected; and
removing liquid components from said fractional distillation column
to storage.
2. In a method of removing ethane and heavier components from an
inlet hydrocarbon gas comprised principally of methane, the
combination of steps comprising:
turbine expanding said gas to produce a gas-condensate mixture
having a temperature below about -50.degree. F.;
fractionally distilling said cooled gas condensate mixture to
remove ethane and heavier components therefrom by passing said
mixture through a low temperature fractionating column having
vertically spaced trays;
withdrawing condensed ethane and heavier components from a lower
portion of said column;
flowing the withdrawn condensed ethane and heavier components to
liquid storage;
withdrawing fractionally distilled non-condensed gas from a top
portion of said column;
flowing the fractionally distilled non-condensed gas through a heat
exchanger to thereby cool said fractionally distilled gas;
flowing additional condensed components from said cooled
fractionally distilled gas and flowing said additional condensed
components back to said column as reflux;
turbine expanding said cooled fractionally distilled non-condensed
gas a second time, the turbine expanders of said first and second
expanding steps being mechanically connected;
flowing twice turbine expanded fractionally distilled non-condensed
gas through said heat exchanger as the cooling medium therefor;
flowing said twice turbine expanded fractionally distilled
non-condensed gas through a second and third heat exchanger as the
cooling medium therefor to cool the inlet gas to produce a first
gas-condensate mixture and to further cool the non-condensed gas
separated from the first gas-condensate mixture to produce a second
gas-condensate mixture, the non-condensed gas of which is fed to
the first turbine and the separated condensates are fed separately
to the column as reflux; and
recompressing said twice turbine expanded fractionally distilled
non-condensed gas after passage through said heat exchangers.
Description
This invention relates to a novel method and system for removing
condensable components from inlet hydrocarbon gas, such as gas
having a high proportion of methane, for example. More
particularly, this invention relates to a low temperature
fractionating method utilizing a novel reflux system and
method.
In the past, there has been need for a method and system of
recovering condensable components from natural gas or the like, as
for example gas having a high proportion of methane.
Certain prior art methods and systems have been developed for
recovering condensable components from such gas, such as systems
particularly for receiving primarily propane, for example. However,
certain of these processes do not provide optimum product
separation or operating flexibility, as with respect to various
operating conditions, for example. Moreover, certain of these
processes are not entirely suitable for ethane recovery in
particular, as opposed to propane, for example.
Examples of such other systems include those described in U.S. Pat.
Nos. 3,292,380; 3,359,743; 2,608,070 and 2,494,126 and in the
article entitled "Low Temperature Gas Processing Operations" by W.
A. Halliburton, Jr., published in the 1968 issue of the Proceedings
of the Forty-Seventh Annual Convention of Natural Gas Processors
Association Technical Papers which papers were presented Mar. 19 -
21, 1968 at New Orleans, La.
It is therefore an object of this invention to provide an improved
low temperature method and system for removing condensable
components, such as ethane and the like from hydrocarbon gas, such
as natural gas having a high proportion of methane.
Briefly stated, the method of this invention contemplates cooling
the inlet gas to below about 0.degree. F. Thereafter the cooled gas
is expanded through expansion means, such as a turbine, to produce
a gas-condensate mixture having a temperature below about
-50.degree. F. The cooled mixture is thereafter fractionated to
remove condensable components therefrom. The fractionated gas is
then flowed through a heat exchanger to thereby cool the
fractionated gas. The fractionated cooled gas is then expanded
again followed by flowing the expanded fractionated gas through the
heat exchanger as the cooling medium. The fractionated gas is then
recompressed by the energy output of the expansion means.
In certain embodiments, the method may include carrying out the
fractionation step in a fractionating column, and withdrawing
liquid from an intermediate point in the column and thereafter
heating the withdrawn liquid to expel methane therefrom, after
which the heated liquid is returned to the column. This may
sometimes be referred to as the side reboiler step.
Briefly stated, the system of the invention includes means for
expanding and thereby cooling the inlet gas passed therethrough,
and gas compressor means driven by the energy output of the
expansion means, for compressing gas passed therethrough. It also
includes means for passing inlet gas through the expansion means to
produce a gas-condensate mixture. A low temperature fractionation
column is included for fractionating the gas-condensate mixture. It
also includes means for delivering the gas-condensate mixture from
the expansion means to the column, and cooling means for cooling
the fractionated gas after withdrawal from the column, to thereby
condensate additional components from the fractionated gas. Means
are provided for passing the cooled fractionated gas after removal
of the condensed components through the expansion means to thereby
expand the cooled fractionated gas. Means are also included for
flowing the expanded fractionated gas through the cooling means as
the cooling medium therefor, and means for passing the expanded
fractionated gas through the compressor means after passage thereof
through the cooling means. The expansion means may include a two
stage turbine expander for carrying out the two expansion steps
discussed above. In certain embodiments, a side reboiler may be
provided for the fractionating column for reheating liquid drawn
from an intermediate point in the column.
Certain embodiments of the apparatus may also include means for
removing the condensed additional components from the fractionating
gas and reflowing such components back to the column as reflux. In
certain instances the aforesaid two-stage turbine may be referred
to as first and second expansion means. Certain embodiments may
also include second cooling means for cooling the inlet gas before
passage thereof through the expansion means and including means for
flowing the expanded fractionated gas through the second cooling
means as the cooling medium therefor. In certain instances the
aforesaid side reboiler may be connected for passage of inlet gas
therethrough as the heating medium. Means may also be provided for
controlling outlet pressure from the fractionation column and for
controlling outlet pressure from the second stage expansion means.
In addition, the system preferably includes a dry bed desiccant
system arranged for dehydrating an inlet gas to a low water dew
point, such as -150.degree. F.
Certain embodiments may include a condensate separator prior to the
first expansion step to remove condensate along with wax, after the
inlet gas has initially been cooled, which condensate and wax
material is directed to the demethanizer column.
Certain embodiments may also include CO.sub.2 removal means
associated with the column for stripping CO.sub.2 from the gas as
it passes through the column. In certain embodiments the heat for
operation of the fractionating demethanizer column may be supplied
by a portion of the recompressed gas which is passed in heat
exchange relationship with the bottoms of the column to thereby
heat the column.
Reference to the drawings will further explain the invention
wherein:
FIG. 1A is the left hand portion and,
FIG. 1B is the right hand portion of a presently preferred system
embodying the invention, in schematic form.
Referring now to the drawings, relatively high pressure hydrocarbon
gas such as methane containing condensable components such as
ethane and propane and heavier components is introduced through
line 1 to a dry bed desiccant system 2 where the inlet gas is
dehydrated to a relatively low water dew point, such as about
-150.degree. F. Desiccant system 2 is preferably of the molecular
sieve type or the like which is capable of achieving the desired
low water dew point, and preferably of the type which may be
regenerated in accordance with the conventional teachings, when
required.
From desiccant system 2 the inlet gas flows through the primary
gas-gas heat exchanger 3 where it is cooled to an appropriate
temperature by exchange with residue gas, to remove any wax and/or
heavy condensate which may be in the gas. From heat exchanger 3,
the resulting condensate and gas flows through line 4 to condensate
separator 5. Separator 5 is capable of phase separation of
hydrocarbon condensate which is withdrawn through line 6 and flowed
to an intermediate tray in stripping section 17 of a fractionating
column, such as demethanizer 16.
The gas is flowed from separator 5 through line 7 to cold gas heat
exchanger 8 where the inlet gas is further cooled to below
0.degree. F. by exchange with residue gas, as will be explained
further hereinafter. Cooled gas leaves heat exchanger 8 through
line 9 where it is directed to scrubber 10 where the liquid
previously condensed by heat exchanger 8 is separated and removed
through line 11 and directed to an upper tray 18 of stripping
section 17 of demethanizer 16.
High pressure gas from scrubber 10 flows through line 12 to first
stage 13 of expansion turbine 51 where the gas undergoes
essentially constant entropy expansion. The work force developed in
turbine 51 is used to drive a booster compressor 35 which is
directly coupled thereto. It is to be noted that gas expander
turbine 51 is a two stage expander and is equipped with inlet
nozzles 14 for controlling the flow or pressure through the system
up to that point.
The two expansion stages 13 and 27 of turbine 51 allow for
separately expanding gas flowed in separate streams therethrough.
Gas expansion turbines of this general type are sold by the
Rotoflow Corporation of Los Angeles, Cal. The design and operation
of a single turbine expander of this type is described in the
article entitled "Turbo Expander Design and Operation" by Judson S.
Swearingen at pages 124 - 127 of the aforesaid Proceedings of the
Forty-Seventh Annual Convention of the Natural Gas Processors
Association Technical Papers, as discussed above.
For purposes of convenience, turbine 51 may sometimes be referred
to as the expansion means. At other times first stage 13 may be
referred to as one expansion means and stage 27 as another
expansion means. In this connection it is to be noted that in
certain embodiments, one of the two stages may be substituted with
a conventional expansion valve, for example, which would in that
case be referred to as one of the expansion means or as being
inclusive in the expansion means. Nevertheless, it is contemplated
that at least one of the expansion means will include a turbine to
drive a sales gas booster compressor such as compressor 35 attached
to the rotor of the gas turbine included in the expansion
means.
The exhaust gas from stage 13 of turbine 51 is then at an
intermediate pressure and cold temperature, and flows through line
15 to demethanizer 16, where the ethane and heavier constituents of
the gas are recovered in the liquid product and the methane is
expelled. It is to be understood that demethanizer 16 is a
conventional fractionating tower having an upper rectifying section
50 and a lower stripping section 17, with both sections having a
plurality of vertically spaced liquid trays 18. It is to be further
understood that demethanizer 16 has outlet means in the upper
portion thereof for passing of non-condensed gas through line 20.
In addition, demethanizer 16 is provided with an outlet at the
bottom thereof connecting with line 29 leading to a product storage
means (not shown). Demethanizer 16 is provided with a conventional
type reboiler in the form of heat exchanger 19, for example. In
this instance a hot heating liquid may be flowed through heat
exchanger 19 in the direction of the arrows 60 and 61 to thereby
heat the bottoms or liquid contained in the bottom of demethanizer
16 and in an enclosed loop indicated by the numeral 62, where the
fluid is flowed in the direction of arrow 63 through the lower
portion of stripping section 17.
Further, when the gas is returned to near inlet pressure by
compressor 35, the product gas at the discharge of compressor 35
will contain adequate heat to reboil demethanizer 16 to thereby
effect a fuel saving, as well as supplying a portion of the cooling
of the gas before it returns to the pipeline for distribution
purposes. Hence, in a preferred embodiment of the invention a
portion of the gas discharged from compressor 35 is directed
through a conduit (not shown) to the hot fluid side of reboiler 19,
where it is heat exchanged with the liquid bottoms of demethanizer
16 to supply reboiled heat to demethanizer 16. The diverted gas
stream is thereafter rejoined with the compressor discharge before
going to the product gas cooler through an appropriate conduit (not
shown).
Passage of the inlet gas through stage 13 of gas expansion turbine
51 allows the fractionation operation to be carried out in
demethanizer 16 at temperatures below about -50.degree. F. It is to
be further understood that demethanizer 16 is a low temperature
intermediate pressure fractionation column which contains a
suitable means, such as conventional trays 18, for intimately
contacting the vapor rising from reboiler 19 and down flowing
condensate. The term "low temperature" fractionating column will
generally be referred to as a column wherein the temperature of the
outlet gas from the upper portion thereof is below about
-50.degree. F.
The outlet or overhead fractionated gas flows from demethanizer 16
through line 20 to demethanizer reflux condenser 21, where the
fractionated gas is cooled by exchange with residue gas as will be
described hereinafter. The cooled fractionated gas and condensate
flow from condenser 21 through line 22 into reflux separator 23.
Reflux separator 23 is arranged to separate out the condensed
fluids which are flowed through line 24 to pump 25 which then pumps
the separated fluid over the rectifying section 50 of demethanizer
16, which serves to condense the ethane and heavier constituents of
the feed gas.
The residue gas flows from the top of separator 23 through line 26
to second stage 27 of gas expansion turbine 51, through inlet
nozzles 28. Nozzles 28 are used to control the pressure on the
demethanizer 16 by opening and closing in response to a pressure
sensor (not shown) in the upper portion of rectifying section 50 of
demethanizer 16. The second expansion step through stage 27 is
operated to produce the required reflux to remove the ethane and
heavier constituents of the gas portion of the feed inlet gas. As
stated above, demethanizer 16 is equipped with a reboiler,
indicated at 19 which serves to vaporize the lighter fractions from
the liquified petroleum gas which is removed through line 29 to
storage.
Demethanizer 16 is also equipped with one or more side reboilers,
such as side reboiler 30 which is a means for providing additional
heat to demethanizer 16 without disturbing the over-all heat
balance. Refrigeration is scavenged by heating the condensate
collected at a relatively high point in the stripping section 17,
which is passed through line 31 to reboiler 30 and back to
demethanizer 16 through line 32. In reboiler 30, the withdrawn
liquid is heat exchanged with a portion of inlet gas supplied
through line 38. After passage of the diverted inlet gas through
side reboiler 30, it is directed back to the gas inlet stream
through line 39 to line 9, thus achieving a colder feed temperature
for the inlet gas. The liquid withdrawn from demethanizer 16
through line 31 is heated inside reboiler 30 to remove methane from
the condensate. As stated above, the heated methane and condensate
is returned to the column through line 32.
The gas which has been directed to second stage 27 of turbine 51 is
expanded and thereby cooled and is thereafter passed through line
33, through heat exchangers 21, 8, and 3 successively and
thereafter through line 34 into booster compressor 35, which in the
embodiment shown is driven by both stages 13 and 27 of turbine 51
by direct coupling thereto as shown. Compressor 35 compresses the
gas to the desired discharge pressure in line 36, which is
preferably below the pressure in the upper portion of demethanizer
16. Generally, the operating pressure of demethanizer 16 will be 20
to 200 psi higher than gas outlet pressure in outlet 36. Back
pressure valve 37 is provided in line 36 to control the outlet
pressure from second stage 27 of turbine 51. The pressure rise
across compressor 35 will be such to satisfy the energy generated
by the gas quantity and pressure differential across both stages 13
and 27 of turbine 51.
When the system is processing gas which must be returned to near
the inlet pressure, the product gas may be compressed independently
by other compressor means, with turbine 51 compression contributing
to the total compression, while at the same time serving the
purposes of feed gas expansion and cooling.
A portion of inlet gas, usually on the order of 10 to 25 percent
thereof, may be directed through line 38, as explained above, for
cooling side reboiler 30 by exchange with tray liquid from
demethanizer 16. The pre-cooled partial inlet gas discharges from
re-boiler 30 through line 39 to combine with line 9 gas flowing
into scrubber 10. The hydrocarbon condensate collected in scrubber
10 undergoes expansion and flash vaporization at valve 40 in
flowing through line 11 to an appropriate location in stripping
section 17 of demethanizer 16.
Similarly, the liquid from condensate separator 5 likewise
undergoes expansion and flash vaporization at valve 41 and is
delivered through line 6 to a likewise appropriate lower tray in
stripping section 17, as shown.
Any wax which may be present in the inlet gas is retained with the
liquid condensate in separator 5 and thereafter fed to an
appropriate tray of demethanizer 16, which tray is set at a level
where the temperature is sufficiently high to prevent the wax from
precipitating and causing a problem, and thus permitting the wax to
be withdrawn from the bottom of demethanizer 16 with the condensed
ethane and other components. The wax in the inlet gas is thereby
maintained at a temperature warm enough to prevent precipitation
and is removed from the system in the liquid condensate. The
initial cooling step carried out by heat exchanger 3 is an
important aspect of this portion of the system for removing wax.
Thus, the system of this invention permits removal of the wax in
separator 5 at a higher temperature than with other systems.
Other features of the system include valves 42 and 43 connected to
control flow respectively through expansion sections 13 and 27 or
to by-pass the same when desired. Valves 42 and 43 allow operation
of the system at reduced LPG recovery when expansion turbine 51 is
out of service for any reason. In addition, valve 44 in line 33
allows for changing between cooling for the purpose of making
reflux in condensor 21 to cooling inlet gas in exchangers 8 and 3,
to thereby effect better product recovery under certain loads and
operating conditions.
In certain installations, it may be desirable to utilize a single
stage expansion turbine in the place of the two stage turbine 51.
In such instances, other expansion means could be substituted for
one of the expansion stages, as for example a conventional
expansion valve, in which event the expansion valve could be placed
at the second stage and substitute for stage 27 of turbine 51 under
certain operating conditions.
In certain embodiments it may be desirable to extract a vapor
stream from demethanizer 16 several trays above re-boiler 19 for
the purpose of treating the stream with molecular sieves or other
suitable means for removal of CO.sub.2. This would be especially
advantageous in systems where the inlet gas contains a relatively
high CO.sub.2 content. Conveniently, such CO.sub.2 removal means
may be in the form of a CO.sub.2 absorption column 70 connected to
line 71 which is arranged to draw gas vapors from demethanizer 16
for passage through column 70 where CO.sub.2 is removed therefrom
by conventional means. Thereafter, the vapor which has been
stripped of CO.sub.2 is returned to demethanizer 16 through line
72, compressor 73 and line 74.
In operation of the aforesaid system and with typical operating
conditions, inlet gas at line 1 may be at a pressure of about 900
psig and may contain approximately 94 percent methane, 2.5 percent
ethane and 2 percent propane and heavier constituents and 1.5
percent combined CO.sub.2 and nitrogen. The combined inlet gas
streams enter condensate separator 5 at about 0.degree. F. Gas
enter scrubber 10 at about -50.degree. F. with a slight pressure
reduction so that the first stage 13 of expander turbine 51 is
driven at about inlet gas pressure. In flowing through stage 13 of
turbine 51, the line 12 gas pressure is reduced to about 400 psig
and about -110.degree. F. temperature. For substantially 60 percent
ethane recovery from demethanizer 16 through line 29, the bottom
temperature of demethanizer 16 is operated at a bottom temperature
of about 100.degree. F. Overhead gas from demethanizer 16 flows
through line 20 to reflux condenser 21 where it is cooled to about
-140.degree. F. and into reflux separator 23 where the reflux is
separated from the residue gas and pumped by pump 25 into the upper
section of demethanizer 16, as shown.
Residue gas flows through line 26 to second stage 27 of expander
turbine 51. In flowing through second stage 27, gas pressure is
reduced to about 300 psi and temperature to about -150.degree. F.
Residue gas in line 33 flows through condenser 21 where it is
exchanged to make reflux and thereafter through gas heat exchanges
8 and 3 where it is exchanged against inlet gas, and thereafter
flowed into booster compressor 35 for delivery from the system
through line 36 at about 360 psig, for example. The pressure under
such operating conditions in the upper portion of demethanizer 16
or at the gas outlet therefrom would be on the order of
approximately 400 psig.
It is to be understood that the foregoing is given as a typical
operating situation and operating perameters can, of course, be
varied to cope with the various conditions which may exist with
respect to the inlet gas which is to be processed and the outlet
gas which is to be produced, as well as the type of liquid
petroleum gas which is to be removed from the inlet gas.
Certain operating ranges have been established for the various
operating conditions and they are recited hereinafter for purposes
of illustration and not as limiting factors on the invention. For
example, typical operating conditions may contemplate inlet gas
pressures in the range of 600 to 1,100 psi. Further, the inlet gas
may contain from 90 to 95 percent methane, 2 to 5 percent ethane, 1
to 3 percent propane and heavier constituents and 1 to 2 percent
combined CO.sub.2 and nitrogen, all of which would be considered
typical conditions for the inlet gas. The combined inlet gas
streams entering scrubber 10 may be on the order of -50.degree. to
-70.degree. F. Further, the first stage expansion of the gas in
stage 13 may reduce the pressure to 350 psi to 450 psi and from
about -90.degree. F. to about -120.degree. F., for example. For
recovery of from 50 to 80 percent of the ethane in the inlet gas,
demethanizer 16 would be operated at temperature ranges from
60.degree. to 150.degree. F. In typical operating conditions, the
reflux condensor 21 may cool the fractionated gas passed
therethrough to a temperature range of -110.degree. to -150.degree.
F., for example. During the flow of gas through second stage 27 of
expander turbine 15, the gas pressure may be reduced to the range
of about 200 psi to 300 psi, for example, and the residue gas
pressure on line 36 may vary from 300 psig to 400 psig. Again, it
is to be understood that the foregoing ranges are for purposes of
illustrating a typical installation under the conditions noted.
However, it is to be understood that these ranges are not to be
considered as limitations upon the invention which will admit to
many variations as will be obvious to those skilled in the art, in
view of the teachings herein.
Applicant's novel method of refluxing allow better product
separation and provides more flexibility in operating conditions.
It is a system and method which is particularly suitable for a high
ethane recovery from the gas where the ethane recovery in this
system may be as high as 40% or more above that for other
systems.
* * * * *