GB1593957A - Creation of Inventions and Patents with Artificial Intelligence

GB1593957A – Cryogenic separation of carbon dioxide from hydrocarbons
– Google Patents

GB1593957A – Cryogenic separation of carbon dioxide from hydrocarbons
– Google Patents
Cryogenic separation of carbon dioxide from hydrocarbons

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Publication number
GB1593957A

GB1593957A
GB7924/78A
GB792478A
GB1593957A
GB 1593957 A
GB1593957 A
GB 1593957A
GB 7924/78 A
GB7924/78 A
GB 7924/78A
GB 792478 A
GB792478 A
GB 792478A
GB 1593957 A
GB1593957 A
GB 1593957A
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United Kingdom
Prior art keywords
demethanizer
carbon dioxide
hydrocarbon
gas
liquid
Prior art date
1977-03-01
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)

Expired

Application number
GB7924/78A
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Standard Oil Co

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Standard Oil Co
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
1977-03-01
Filing date
1978-02-28
Publication date
1981-07-22

1978-02-28
Application filed by Standard Oil Co
filed
Critical
Standard Oil Co

1981-07-22
Publication of GB1593957A
publication
Critical
patent/GB1593957A/en

Status
Expired
legal-status
Critical
Current

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Classifications

C—CHEMISTRY; METALLURGY

C07—ORGANIC CHEMISTRY

C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS

C07C7/00—Purification; Separation; Use of additives

C07C7/04—Purification; Separation; Use of additives by distillation

C07C7/05—Purification; Separation; Use of additives by distillation with the aid of auxiliary compounds

B—PERFORMING OPERATIONS; TRANSPORTING

B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL

B01D—SEPARATION

B01D3/00—Distillation or related exchange processes in which liquids are contacted with gaseous media, e.g. stripping

B01D3/14—Fractional distillation or use of a fractionation or rectification column

B01D3/32—Other features of fractionating columns ; Constructional details of fractionating columns not provided for in groups B01D3/16 – B01D3/30

B01D3/322—Reboiler specifications

F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING

F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES

F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE

F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification

F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream

F25J3/0204—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the feed stream

F25J3/0219—Refinery gas, cracking gas, coke oven gas, gaseous mixtures containing aliphatic unsaturated CnHm or gaseous mixtures of undefined nature

F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING

F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES

F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE

F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification

F25J3/0228—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream

F25J3/0242—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream separation of CnHm with 3 carbon atoms or more

F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING

F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES

F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE

F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification

F25J3/0247—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream separation of CnHm with 4 carbon atoms or more

F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING

F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES

F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE

F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification

F25J3/0266—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream separation of carbon dioxide

F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING

F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES

F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE

F25J2200/00—Processes or apparatus using separation by rectification

F25J2200/02—Processes or apparatus using separation by rectification in a single pressure main column system

F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING

F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES

F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE

F25J2200/00—Processes or apparatus using separation by rectification

F25J2200/70—Refluxing the column with a condensed part of the feed stream, i.e. fractionator top is stripped or self-rectified

F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING

F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES

F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE

F25J2205/00—Processes or apparatus using other separation and/or other processing means

F25J2205/02—Processes or apparatus using other separation and/or other processing means using simple phase separation in a vessel or drum

F25J2205/04—Processes or apparatus using other separation and/or other processing means using simple phase separation in a vessel or drum in the feed line, i.e. upstream of the fractionation step

F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING

F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES

F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE

F25J2210/00—Processes characterised by the type or other details of the feed stream

F25J2210/12—Refinery or petrochemical off-gas

F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING

F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES

F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE

F25J2280/00—Control of the process or apparatus

F25J2280/02—Control in general, load changes, different modes (“runs”), measurements

F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING

F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES

F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE

F25J2290/00—Other details not covered by groups F25J2200/00 – F25J2280/00

F25J2290/40—Vertical layout or arrangement of cold equipments within in the cold box, e.g. columns, condensers, heat exchangers etc.

Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS

Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE

Y02C—CAPTURE, STORAGE, SEQUESTRATION OR DISPOSAL OF GREENHOUSE GASES [GHG]

Y02C20/00—Capture or disposal of greenhouse gases

Y02C20/40—Capture or disposal of greenhouse gases of CO2

Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE

Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS

Y02P20/00—Technologies relating to chemical industry

Y02P20/151—Reduction of greenhouse gas [GHG] emissions, e.g. CO2

Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC

Y10S—TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS

Y10S62/00—Refrigeration

Y10S62/928—Recovery of carbon dioxide

Y10S62/929—From natural gas

Description

PATENT SPECIFICATION ( 11) 1 593 957
i ( 21) Application No 7924/78 ( 22) Filed 28 Feb 1978 ( 19)( > ( 31) Convention Application No 773359 ( 32) Filed 1 Mar 1977 in ( 33) United States of America (US)
) ( 44) Complete Specification Published 22 Jul 1981
U 1 ( 51) INT CL 3 F 25 J 3/02 ( 52) Index at Acceptance F 4 P 905 931 958 961 FB 1 ( 54) CRYOGENIC SEPARATION OF CARBON DIOXIDE FROM HYDROCARBONS ( 71) Wc, STANDARD OIL COMPANY, a Corporation organised and existing under the laws of the State of Indiana, United States of America, of 200 East Randolph Drive, Chicago Illinois 60601, United States of America, do hereby declare the invention for which we p ray that a patent may be granted to us and the method by which it is to be perfolmed, to be particularly described in and by the following statement: 5
1 l’he present invention relates to an improved process for cryogenic separation of hydrocarbons in the presence of a relatively high carbon dioxide content wherein the hydrocarbon/carbon dioxide feed gas after precooling and turboexpansion is directed to a demethanizer column for the purpose of separating a methane/carbon dioxide overhead from an ethane-containing liquid hydrocarbon bottoms More specifically, it is concerned 10 with improving and stabilizing the operation of the demethanizer column.
High carbon dioxide content feed gases such as may be encountered in certain fields of the United States which may range in carbon dioxide content between O 1 and 15 % by volume continue to be a problem to the extent that cryogenic handling procedures may cause separation from the feed gas of carbon dioxide as “ice” with destructive effect on 15 equipment and efficiency Traditionally, carbon dioxide has been separated in advance of processing for hydrocarbon product separation with an added step such as amine treating, molecular sieve adsorption, methanol adsorption or caustic treating or not removed, see for example U S Patent No 3,292,380 to Bucklin In cases where the carbon dioxide is not removed from the feed gas, it must be removed from the product ethane by one of the 20 above-mentioned sweetening processes.
In U S Patent No 3,595,782 to Bucklin et al, a method for producing an ethane-containing liquid hydrocarbon essentially free of both methane and carbon dioxide without carbon dioxide icing to foul equipment is disclosed The process involves passing an expanded precooled feed gas through a demethanizer separation column at a temperature 25 below -800 F and pressure consistent with maintaining the non-gaseous carbon dioxide dissolved in an ethane-containing liquid hydrocarbon phase Thus, carbon dioxide icing does not occur and an ethane output substantially free of carbon dioxide; e g, less than 0.1 % carbon dioxide content, can be achieved However, in operating such a plant on a commercial scale, the carbon dioxide content in the liquid product is extremely sensitive to 30 the reboiler temperature at the bottom of the demethanizer For example, in one commercial scale plant, it was observed that at design level a one-degree change in the reboiler temperature would result in rapid temperature drops in selected tray temperatures and an increase in carbon dioxide content in the liquid product from essentially zero to a value that exceeded the specification limit Under such circumstances, closed-loop control 35 of the reboiler temperature based on gas chromatograph carbon dioxide to ethane ratio measurements and the like is not posssible.
In view of the criticality of controlling the reboiler temperature at the base of a cryogenic demethanizer, we have discovered an improved method of operating the demethanizer such that the separation process is stabilized and desensitized with respect to reboiler 40 temperature fluctuations The improvement involves injecting an appropriate stream of gas with, preferably, a methane content greater than that in the reboiler vapors into the bottom of the demethanizer The dehydrated hydrocarbon feed gas being processed in plant is an acceptable source of stripping gas The rate of injection is maintained such that the bottoms product methane content remains sufficiently low to meet commercial standards (usually 45 1 593 957 about 0 1 to 1 0 liquid volume percent).
Thus, a primary objective of this invention is to provide a method for producing an ethane and heavier hydrocarbon product having a low carbon dioxide and methane content from gas having objectionable amounts of carbon dioxide in a cryogenic demethanizer in a manner such that the quantity and quality of ethane being produced will not be 5 compromised because of minor temperature excursions which occur at the bottom of the demethanizer column.
Accordingly, this invention provides in a method of treating hydrocarbon feed gas having relatively high carbon dioxide content to produce a liquid ethanecontaining hydrocarbon product substantially free of carbon dioxide and a gaseous product comprising methane and 10 carbon dioxide said method comprising a) expanding a precooled gaseous portion of said hydrocarbon feed gas through a turbine to produce a mixture of gaseous hydrocarbon, including methane, and liquid hydrocarbon, including liquid ethane, said mixture being at at temperature below -800 F; 15 b) passing said mixture to a demethanizer separation column at a temperature below -800 F; c) separating said mixture in said demethanizer such that essentially all the methane and gaseous carbon dioxide are recovered overhead as said gaseous product and essentially all said liquid hydrocarbon, including liquid ethane, is 20 recovered towards the bottom of said demethanizer as said liquid ethanecontaining hydrocarbon product, while maintaining non gaseous carbon dioxide dissolved in said liquid ethane-containing hydrocabon in said turbine and said demethanizer, and d) reducing the sensitivity of the separation process in the demethanizer with respect to temperature variation in the liquid bottoms of the demethanizer by 25 injection into the ethane-containing liquid hydrocarbon at or adjacent the bottom of the demethanizer separation column of a gas which is inert (as defined herein) and does not liquify under the conditions in the demethanizer separation column.
The invention will now be described in greater detail with reference to one embodiment thereof and with the aid of the accompanying drawings, in which: 30 Figure 1 of the drawing is a flow diagram of a specific cryogenic method of separating carbon dioxide from hydrocarbons which is known in the prior art and is presented here to illustrate the basic modification required to perform the improvement which is the subject of this invention, Figure 2 of the drawing is a flow diagram illustrating the improved process of this 35 invention in more detailed terms than Figure 1 including an associated closed-loop chromatographic control scheme.
Referring to the drawings, Figure 1 is a simplified flow diagram of a specific cryogenic method of separating carbon dioxide from hydrocarbons as already known in the art It is presented here to illustrate 40 conceptually how the modifications involved in this invention fits into the overall flow diagram of a typical commercial embodiment Briefly, the known process involves passing dehydrated high pressure hydrocarbon feed containing carbon dioxide through a heat exchanger 1 to precool the feed The resulting liquid and gas mixture is then separated in tank 2 The gas phase from this separation is sent through a turbine expander 3 before 45 entering the top of the demethanizer column 4 The condensed phase from this separation is injected midway down the demethanizer column The conditions within the demethanizer are maintained below -800 F and at an appropriate pressure such that essentially all of the methane and carbon dioxide are separated and withdrawn overhead while any non-gaseous carbon dioxide remains in solution with the liquid ethane and higher molecular weight 50 hydrocarbons being withdrawn from the bottom The bottoms then undergo further fractionation in a separate distillation column 5 with ethane and propane being removed overhead and then used to supply heat to the reboiler heat exchanger 6 at the bottom of the demethanizer The butane and heavier cut is recovered at the bottom of the second distillation column to complete the process As previously stated, this process is basically 55 known in the art and the purpose of presenting Figure 1 is to show how the present improvement is incorporated into a known specific embodiment Dashed line 7 which delivers a portion of the dehydrated feed gas to the demethanizer and injects it as a sweep gas at point 8 is illustrative of the basic improvement of our invention For a more detailed description of the known process, less this improvement, see U S Patent 3, 595 782 60
In Figure 2 the details of a typical commercial scale 30-tray demethanizer 10 being operated according to the present invention is illustrated along with a reboiler 12 and an associated gas chromatograph 14 for control of the bottom reheat temperature The gas phase hydrocarbon passing through the turboexpander (not shown) enters the demethanizer 10 via line 15 at the top while the condensed phase from the expander feed separator (not 65 1 593 957 shown) enters midway to tray #18 through line 16 A portion of the original dehydrated hydrocarbon feed gas contaminated with carbon dioxide is intentionally added towards the bottom of the demethanizer 10 through line 17 as a sweep gas which admittedly enriches the entire column and to a certain degree the liquid ethane-containing bottoms with gases which in principle are to be cryogenically distilled overhead It is this intentional addition of 5 a purge gas at the bottom of the demethanizer which forms the basis of our invention and serves to distinguish the present improved process from that which has been practiced in the past.
Two product streams are recovered from demethanizer 10 A methane and carbon dioxide mixture is removed overhead via line 19 and a liquid ethanecontaining 10 hydrocarbon product stream is withdrawn from the bottom through line 20 In order to control the bottom temperature by supplying the proper amount of heat to the bottom of the demethanizer 10, demethanizer liquids are removed via line 21 and send through reboiler heat exhanger 12 The temperature controlled liquid and vapor stream is then returned to the demethanizer through line 22 Heat energy is supplied to the reboiler 12 15 from an external heat medium circulating in line 23 The heat medium enters the reboiler 12 via control valve 24 and line 25 After passing through the reboiler, it returns to line 23 via line 26.
Automation of the reboiler temperature control is achieved by removal of a sample of the demethanizer liquid from line 21 This sample is sent via line 27 and valve 28 to gas 20 chromatograph 14 wherein the carbon dioxide to ethane ratio is measured The difference between this measured value and a predetermined setpoint value characteristic of the desired product composition is transmitted in the form of an electrical signal through dashed line 29 to a current to pneumatic converter 30 A corresponding pneumatic signal is then transmitted via line 31 to a temperature reset controller 32 Controller 32 responds by 25 reassigning a new temperature range to temperature controller 33 via line 34 Controller 33 then brings the temperature of the fluid in line 22 being monitored by temperature transmitter 35 back into agreement with the new reset temperature range by repositioning the valve 24 In this manner, the amount of jacket water, the heat medium, flowing through the reboiler is controlled so as to maintain the desired temperature of the reboiler effluent 30 being returned to the bottom of the demethanizer and this temperature is reset automatically according to the measured concentration of carbon dioxide present in the liquid bottoms relative to a desired product specification limit.
The significance and practical advantage of practicing our improved cryogenic separation method can perhaps best be demonstrated by considering the details of a typical 35 commercial scale plant being operated according to the preferred embodiments illustrated in Figure 1 and Figure 2 with and without the injection of the dehydrated sweep gas For example, a 30-tray demethanizer having a tray efficiency of 50 percent ( 15 theoretical trays) and an expander efficiency of 70 percent when operated according to Figure 1 without sweep gas injection at a design flow rate of 40 MMSCF (million cubic feet per day) of a feed 40 gas having the composition set out in the following Table I at a demethanizer pressure of 250 psia and reboiler effluent controlled bottom temperature of 48 20 F would be expected to produce an overhead methane/carbon dioxide residue gas having a gross heating value in excess of 1000 BTU/SCF and produce a liquid bottoms product stream having less than 0 75 volume percent carbon dioxide with ethane and propane recoveries of 58 7 and 95 4 45 percent, respectively.
TABLE I
Inlet gas Analysis 50 Component Mol Percent Nitrogen 0 30 Carbon Dioxide 0 45 55 Methane 93 32 Ethane 3 99 Propane 1 27 i-Butane 0 14 n-Butane 0 26 60 i-Pentane 0 08 n-Pentane 0 06 Hexanes Plus 0 13 00 1 593 -957 Such a plant, when operated at design recovery levels, exhibited extreme sensitivity to reboiler temperature in that a one-degree change in reboiler temperature caused certain tray temperatures to drop rapidly and caused the carbon dioxide content in the liquid product to increase from a zero gas chromatographic measured value to a value exceeding acceptable liquid product specification In this particular case, closedloop gas chromatog 5 raphic control of reboiler temperature was for all practical purposes inoperative.
The magnitude of the instability induced by a one-degree change in the above example can be illustrated by considering tray 6 At a reboiler temperature of 490 F, the temperature of tray 6 is 16 ‘F At 480 F the temperature falls to -430 F, a change of 590 F The large tray temperature change is caused by correspondingly large carbon dioxide and ethane 10 concentration changes Lowering the reboiler temperature from 490 F to 480 F will create an anticipated change of the carbon dioxide content in the liquid of tray 6 from 2 4 to 37 mole percent and in the vapor from 6 9 to 62 8 mol percent Simultaneously, the ethane content of tray 6 in the liquid decreases from 77 3 to 41 2 mol percent and in the vapor from 85 1 to 20 6 mol percent Obviously, when a large increase in the concentration of the more volatile 15 component occurs, a drastic drop in the equilibrium temperature will be observed It is this tremendous reboiler temperature sensitivity and associated separation column instability that is alleviated by the use of an appropriate purge stream injection at the bottom of the demethanizer.
Injecting stripping gas in the bottom of the demethanizer has a positive effect on product 20 recovery and tower controllability Table II below, summarizes the recovery levels for three cases, the first without stripping gas and the second and third with 750 MSCFD (thousand standard cubic feet per day) of dehydrated feed gas being injected.
TABLE II 25
Stripping Reboiler Reboiler Gas Rate Temp Recovery % Duty 30 Case MSCFD OF Ethane Propane MMBTU/HR 1 0 48 2 58 7 95 4 1,495 2 750 48 2 49 2 94 7 1 465 3 750 40 7 60 3 95 7 1 331 35 (million BTU per hour) In each case the demethanizer pressure is 250 psia, and in Case 1 and Case 3 the product meets carbon dioxide concentration specification Case 3 showed the highest ethane and 40 propane recovery Injecting stripping gas also increases recovery by allowing retention of methane in the liquid product A purchaser will customarily pay for methane in the product up to some contractually specified limit, e g, 0 75 volume percent Case 3 relative to Case 1 takes greater advantage of this factor in the sense that liquid product presently sells at about ten times the price of the methane/carbon dioxide residue gas But, most important, Case 3 45 is compatible with gas chromatograph closed-loop control of the reboiler temperature without severe demethanizer instability.
An effective amount of sweep gas for purposes of this invention refers to sweep gas flow rates that range from about one-fortieth up to about one-four hundreth of the flow rate of the feed gas being processed In principle, this sweep gas can be gas which is inert (i e 50 which does not react with other components of the feed under the conditions of operation) and does not liquefy under the operation conditions Since the sweep gas dilutes the demethanizer overhead stream, it is preferable to use a methanecontaining sweep gas The rate of injecting the methane-containing sweep gas has been successfully tested from as low as 120 MCFD to as high as 750 MCFD in the above example However, other rates would 55 be acceptable and for purposes of this invention should be considered equivalent The pragmatic consideration of methane content tolerable in the final product should in principle be the primary factor in determining an upper limit Thus, the specific rate will vary from plant to plant, and will also vary with feed gas composition and operating conditions 60 A liquid ethane-containing hydrocarbon product, substantially free of carbon dioxide for purposes of this invention, is referring to carbon dioxide concentrations of about 1 0 to 3 0 liquid volume percent or less, and preferably 0 1 liquid volume percent Having thus described the preferred commercial scale embodiment, it should be apparent that the basic invention can be employed with other types of analytical monitors than gas chromatogra 65 1 593 957 5 phy, other known flow and temperature control systems as well as other chemically similar purge systems.

Claims (4)

WHAT WE CLAIM IS:

1 A method of treating hydrocarbon feed gas having a relatively high carbon dioxide content to produce a liquid ethane-containing hydrocarbon product substantially free of 5 carbon dioxide and a gaseous produce comprising methane and carbon dioxide, said method comprising a) expanding a precooled gaseous portion of said hydrocarbon feed gas through a turbine to produce a mixture of gaseous hydrocarbon, including methane, and liquid hydrocarbon, including liquid ethane, said mixture being at a temperature below 10 ‘F; b) passing said mixture to a demethanizer separation column at a temperature below -80 “F; c) separating said mixture in said demethanizer such that essentially all the methane, and gaseous carbon dioxide are recovered overhead as said gaseous 15 product and essentially all said liquid hydrocarbon, including liquid ethane, is recovered towards the bottom of said demethanizer as said liquid ethanecontaining hydrocarbon product, while maintaining non gaseous carbon dioxide dissolved in said liquid ethane-containing hydrocarbon in said turbine and said demethanizer, and 20 d) reducing the sensitivity of the separation process in the demethanizer with respect to temperature variation in the liquid bottoms of the demethanizer by injection into the ethane-containing liquid hydrocarbon at or adjacent the bottom of the demethanizer separation column of a gas which is inert (as defined herein) and does not liquify under the conditions in the demethanizer separation column 25

2 A method of Claim 1 wherein said sweep gas is a dehydrated methanecontaining gas.

3 A method of Claim 2 wherein said dehydrated methane-containing sweep gas is taken from said hydrocarbon feed gas.

4 A method of Claim 3 wherein the flow rate of said dehydrated methanecontaining 30 sweep gas is from about one-fortieth to about one four hundredth of that said hydrocarbon feed gas.
A method of Claim 3 wherein said hydrocarbon feed gas is being processed at about million standard cubic feet per day at about 250 psia, with the addition of from 120 to 750 thousand cubic feet per day of said sweep gas 35 6 A method as claimed in Claim 1, substantially as hereinbefore described with particular reference to the accompanying drawings.
MATHYS & SQUIRE.
Chartered Patent Agents, 40 Fleet Street, London EC 4.
Agents for the Applicants.
Printed for Her Majesty’s Stationery Office, by Croydon Printing Company Limited Croydon, Surrey 1981.
Published by The Patent Office, 25 Southampton Buildings London WC 2 A l AY, from which copies may be obtained.

GB7924/78A
1977-03-01
1978-02-28
Cryogenic separation of carbon dioxide from hydrocarbons

Expired

GB1593957A
(en)

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US05/773,359

US4185978A
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1977-03-01
1977-03-01
Method for cryogenic separation of carbon dioxide from hydrocarbons

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GB1593957A
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1981-07-22

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GB1593957A
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1977-03-01
1978-02-28
Cryogenic separation of carbon dioxide from hydrocarbons

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CA1096624A
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1978-03-01
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Withdrawn

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DE2808838A1
(en)

1978-09-07

CA1096624A
(en)

1981-03-03

US4185978A
(en)

1980-01-29

NL7801874A
(en)

1978-09-05

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