US3675435A

US3675435A - Low pressure ethylene recovery process

Info

Publication number: US3675435A
Application number: US874842A
Authority: US
Inventors: Steven B Jackson; Ernest Freireich; James D Hammond
Original assignee: Fluor Corp
Current assignee: Fluor Corp
Priority date: 1969-11-07
Filing date: 1969-11-07
Publication date: 1972-07-11
Anticipated expiration: 1989-07-11
Also published as: DE2053244B2; ES385316A1; GB1291745A; DE2053244A1; JPS5146074B1; NL151972B; NL7016247A; FR2069123A5; BE758567A

Abstract

Process for the removal of methane from a hydrocarbon feed containing ethylene, methane and higher boiling hydrocarbons with minimum loss of ethylene. Methane is separated overhead from the feed in a separation zone at a first lower pressure; a first portion of this overhead vapor is expanded through an expansion motor producing an energy output, a second portion of the overhead vapor is compressed to a second pressure greater than the first pressure in a compressor driven by the motor output. The compressed vapor portion is then cooled to condense the major portion of the methane and the condensed methane is returned to the separation zone as reflux and recovering ethylene as bottoms from the separation zone. The methane vapor is recovered as fuel gas.

Description

United States Patent Jackson et al.

451 July 11,1972

[54] LOW PRESSURE ETHYLENE RECOVERY PROCESS [72] inventors: Steven 8. Jackson, Fullerton; Ftnest helreleh, Los Angela; James D. Harnrnond, Alhambra, all of Calif.

[73] Assignee: Fluor- Corporation, Los Angeles, Calif. [22] Filed: Nov. 7, 1969 [2!] Appl. No.: 874,842

Related US. Application Data [63] Continuation-impart of Ser. No. 800,875, Feb. 20,

[52] US Cl .62/26. 62/39, 62/28, 62/23 [5|] lnLCl ..F25j3/02 [58] Field ol'Search ..62/23, 24, 26, 27, 28, 30, 62/39. 40

[56] References Cited UNITED

STATES PATENTS

3,3 77,8! l 4/1968 Siegrist et a]. ..62/26 3,2923 80 12/1966 Bucklin .....62/26 3,292,381 [2/1966 Bludworth .6212! Primary ExaminerNorman Yudkofi' Asrr'rlanr xamr'nerA. F. Purcell Arromey--White and Haetliger [57] ABSTRACT Process for the removal of methane from a hydrocarbon feed containing ethylene, methane and higher boiling hydrocarbons with minimum los of ethylene. Methane is separated overhead from the feed in a separation zone at a first lower pressure; a first portion of this overhead vapor is expanded through an expansion motor producing an energy output, a second portion of the overhead vapor is compresed to a second presure greater than the first pressure in a compressor driven by the motor output. The compresed vapor portion is then cooled to condense the major portion of the methane and the condensed methane is returned to the separation zone as reflux and recovering ethylene as bottoms from the separation zone. The methane vapor is recovered as fuel gas.

l6Clalms,lDrawlngFlgure PATENTEUJHL 1 1 I972 0 awmm w mma E kw M H m NJP. #7 Him 2% EE TE 5 LOW PRESSURE ETI-IYLENE RECOVERY PROCESS REFERENCE TO RELATED APPLICATION This application is a continuation-in-part of our copending application, Ser. No. 800,875, filed Feb. 20, 1969.

BACKGROUND OF THE INVENTION 1 Field of the Invention This invention is concerned with the processing of cracked gases derived from hydrocarbon feedstocks and specifically with processing operations having as their ultimate objective the economical recovery of maximum quantities of ethylene from such feedstocks. The present invention provides a process adapted to the recovery of ethylene from ethylenecontaining feed gases which typically contain as well as hydrogen, appreciable quantities of methane and various heavier ends such as ethane, propane and propylene. Particularly significant in the present development is the effective separation of methane from the ethylene at relatively low pressures and at moderate refrigeration temperatures whereby much high pressure equipment is obviated and/or expensive methane refrigeration plant requirements are avoided.

2. Prior Art Recovery of ethylene from ethylene-containing gases is widely practiced in industry. Most operations have as their central facility a demethanizer column from which methane is passed overhead and ethylene is taken as bottoms. Typical operating conditions include 450 psia pressure in the column and accumulator temperatures of about l40F. This combination keeps ethylene loss low lpercent) but is disadvantageous in that the high pressure in the demethanizer results in a greater than necessary total compressor energy requirement for refrigeration and raw gas compressors. Increased demethanizer pressure is even counterproductive as methane/ethylene separation is relatively more difficult at increased pressures.

Some ethylene recovery plants have so-called low pressure demethanizers. These, however, have been combined with expensive methane refrigeration cycles to produce a sufficiently low temperature for minimizing ethylene losses with the separated methane, so that the pressure-temperature problem referred to above is shifted but not resolved.

SUMMARY OF THE INVENTION A different approach to the ethylene recovery problem is taken by the present invention where the methane/ethylene separation is achieved at relatively low pressures, but still with the application of no colder external refrigerant temperatures than those possible with the use of ethylene. In this manner the high pressure facilities required in the plant are much reduced and operating costs are similarly lessened. As a particular feature, motor energy from an expander such as turbo-expander, driven by expansion of a portion of demethanizer overhead vapors is used to compress a second portion of these overhead vapors, which are cooled by external ethylene refrigeration and partially condensed, thus providing reflux for the demethanizer without external methane refrigeration being required.

Specifically, the invention provides a process for the removal of methane from a hydrocarbon feed containing ethylene, hydrogen, methane and higher boiling hydrocarbon components with low loss of ethylene. The process includes effecting in a methane separation zone at a first pressure between about 200 and 350 psia. a separation overhead of methanerich vapor which may contain up to 4 percent hydrogen and less than 2 percent ethylene by volume, expanding a first portion of the overhead vapor through an expansion motor producing an energy output from the vapor expansion, compressing a second portion of the overhead vapor to a second pressure greater than the first pressure in a compressor driven by the energy output of the motor, cooling the compressed overhead vapor portion sufficiently to condense the major portion of the methane therein, separating methane vapor from the condensed methane, returning the condensed methane to the methane separation zone as reflux and recovering ethylene and heavier components of the feed as bottoms from the methane separation zone. The first vapor portion generally will comprise not less than 50 percent by volume of the methane separation zone overhead and the second overhead vapor portion accordingly will be less than 50 percent by volume of the methane separation zone overhead vapors. The expansion of the first overhead vapor portion is carried out to produce an energy output which will effect the desired compression of the second overhead vapor portion. In particular embodiments, the overhead first vapor portion is expanded to a pressure less than I00 psia while the second portion of the overhead vapor is compressed to a pressure above about 450 psia.

In preferred embodiments the first vapor portion is centrifugally expanded through a turbine type expansion motor.

The process further includes flashing hydrogen and methane from the hydrocarbon feed in advance of the methane separation zone and heat exchanging the flash vapor and flash liquid with incoming feed to cool the feed before flashing hydrogen and methane therefrom. In addition, heat exchanging the expanded overhead vapor portion with the feed to cool the feed further prior to said flashing may also be accomplished in the process. Further included is heat exchanging the bottoms from the methane separation zone with the feed to cool the feed prior to flashing methane and hydrogen therefrom. The second vapor portion may be compressed to a pressure above about 450 psia and thereafter be cooled by external refrigeration to a temperature below about l3SF, to efiect liquefaction of from 50 to percent of the methane content in the portion.

BRIEF DESCRIPTION OF THE DRAWING The single FIGURE schematic flow sheet illustrates one embodiment of the present invention.

DESCRIPTION OF THE PREFERRED EMBODIMENTS It will be apparent from the foregoing and as the description proceeds that the present invention provides separation of methane during ethylene recovery at temperatures no lower than those realizable with ethylene refrigerants at ordinary pressures, e.g. l45F and with a minimum of high pressure equipment. Moreover, this process effectively balances power outputs and demands, and heating and cooling requirements, to secure high efiiciency in operation.

Thus, and with reference to the accompanying flow sheet drawing, the feed enters along line I at a temperature generally of -40 to +60F and at pressures typically between 235 and 550 psia for example 420 psia. The cold process streams available from subsequent operations, to be described, are used to advantage to cool the feed, prior to fractionation of the feed, to temperatures at which hydrogen and methane may be flashed from the feed e.g. I20F to l40F. Feed from line I is split to send a first portion to heat exchanger 2 along line 3. In passage along line 3, this first portion of the feed is heat exchanged in heat exchanger 4 with the product recovery stream in line 53 prior to passing the product stream to subsequent processing equipment, e.g. a deethanizer (not shown). The first portion of the feed may also be cooled with auxiliary cooling means such as propylene refrigeration in heat exchanger 5, ethylene refrigeration in heat exchanger 6 as required to achieve the desired temperature in the feed.

The second portion of the feed controlled by valve 7 bypasses heat exchangers 4, 5 and 6 and passes along line 8 to heat exchanger 9 where this feed portion is cooled by heat exchange with exiting hydrogen-rich and methane-rich gas streams in

lines

10 and 11 respectively. The off-gas cooled, second feed portion is returned along line 12 to line 3 for recombination with the cooled feed first portion at 13.

Thus preliminarily cooled, the feed passes to a gas-liquid separator 14 having level control valve Ma, so that the feed enters separator M at approximately 120F. ln separator 14, gas and liquid phases are flash separated at a pressure of approximately 405 psia. The flash liquid from this phase separation is taken as bottoms from separator 14 along line 15 and forms the main feed to the demethanizing zone, after reheating to optimum temperature in heat exchanger 2, as will be described. The flash vapor from separator l4 is taken overhead in line 16 and cooled drastically in heat exchanger 17 eg. to 2l0F at 400 psia by heat exchange therein with very cold methane gas and liquid erg. -2l8F in line ll from the vapor expansion hereinafter described and passed along line 18 to be flashed in gas-liquid separator 19 having a pressure control valve 190. The flash vapors from separator 19 constitute a cold, hydrogen-rich gas stream which may be passed along line 10 as a refrigerating stream to be heat exchanged with the feed in heat exchanger 9 before leaving the system eg at +52F.

The flash liquid from the second flash in separator 19 is passed from the separator along line 20 having level control valve 200, reheated against the first flash vapors in heat exchanger [7 and thereafter combined at 21 with the gross demethanizer column overhead stream in line 28.

Considering again the first flash separator 14, flash liquid taken off in line 15 controlled by level control valve 140 is passed through heat exchanger 2 for warming, e.g. to 75F and is then passed to fractionating column 22 at feed point 23 in the column. Column 22 is operated as the demethanizer first stage. Pressure in bottoms section 24 of column 22 is relatively low for a demethanizing operation e.g. between 200 and 350 psia and suitably about 265 psia. Bottoms temperature is maintained with reboiler loop 25 by condensation of propylene refrigeration vapors from line 26 at a level sufficient to boil the bottoms mixture of C,-C and heavier hydrocarbons e.g. 5F.

The upper section 27 of column 22 above the feed point 23 is operated at a slightly lower pressure and at a lower temperature than the column bottom section 24, e.g. at 260 psia and 1 10F. Temperatures in upper section 27 may be between 70 and lF and pressures may range between l95 and 340 psia. The gross demethanizer overhead from column upper section 27 comprising predominantly methane and some minimum quantity of ethylene e.g. 4 to 7 percent is passed along line 28 to rectification in rectifier 29. The gross demethanizer overhead is cooled in heat exchanger 30 with l 47F ethylene prior to introduction into the rectifier 29. As previously described, the flash liquid from separator 19 is added to the gross demethanizer overhead at point 21 in line 28, following heat exchanger 30. The gross demethanizer overhead is passed into the bottom of rectifier 29 which is suitably maintained at a pressure of 255 psia and a temperature of l40F, both below their corresponding values in upper section 27 of column 22. Liquid bottoms from the rectifier 29 is passed by pump 31 along line 32 through valve 324 to the upper section 27 of demethanizer column 22, as reflux.

The overhead from rectifier 29 comprising methane and 2 to 4 percent hydrogen and minimum ethylene eg 0 to 2 percent and preferably 1 percent by weight and typically at a temperature of -l65F is passed along line 33 to a turbo-expander 34 through heat exchanger 46 for warming. The turboexpander includes an expander section 35, typically a centrifugal expander which is operated as an expansion motor and a compressor section 36 also centrifugal, which is operated as a compressor, driven by the expander section to which it is directly coupled, as by a motor. The term expansion motor" herein is used to describe devices producing mechanical energy through gas or vapor expansion. While turbine motors are preferred reciprocating motors may be used.

The rectifier overhead line 33 communicates along line 37 with the inlet 38 of expander section and along line 39 with the suction inlet 40 of the compressor section 36, whereby the rectifier overhead vapors in line 33 are divided into two portions, at 41, for passage to either the expander or compressor sections 35, 36 along

line

37 or 39 respectively. Moreover, by control valve 42 operation a portion of the rectifier overhead can bypass the expander and pass directly to line ll e.g. in heat exchanger 17 as shown.

Post-fractionation compression of a portion of the rectifier overhead vapors provides a capability in the present process for maximum ethylene recovery without operating the fractionation column 22 at critical values of temperature or at unduly high pressure. Thus in compressor section 35, the rectifier overhead vapors are compressed to a pressure at which the major portion Le. 50 percent by volume and above, e.g. 50 to 75 percent up to 95 percent of the methane component thereof is condensible against readily available streams such as cold ethylene, e.gt ethylene at 147F. Total condensation is not economically feasible due to the necessary inclusion of small concentrations of hydrogen in the methane overhead from rectifier 29, which in turn results from solution of minor amounts of hydrogen in the liquids separated in separators l4 and 19. Suitable pressures in the compressed overhead vapors from compressor operation range between 450 and 600 psia with pressures between 475 and 550 psia being typical. The pressurized vapors generally emerge from the compressor section 35 at a somewhat increased temperature e. g. from to OF. The compressed vapor is passed from compressor section 35 along line 43 to heat exchanger 30 where the compressed vapors are cooled and partially condensed by ethylene refrigeration at l 47F for passage along line 44 to gas liquid separator 45 through heat exchanger 46 providing heat exchange with the rectifier overhead in line 33 which comprises cold methane-rich vapor. The methane overhead from separator 45 is passed along line 47 through pressure control valve 47a to line 33 at point 48 for combination with gross overhead stream to the turboexpander 34.

The liquid from separator 45 comprising substantially liquid methane is passed along line 49, controlled by level control valve 490, back to rectifier 29 as reflux at feed point 50, ultimately to be recovered as overhead vapor from rectifier 29 in line 33 or as liquid methane in line 51 to be combined at 52 with expanded methane from expander section 35 leaving the system in line 11.

The bottoms from column 22 comprising ethylene together with any heavier ends present in the feed are recovered as bottoms from line 53 having pump 54 and control valve 540. From a feed containing about 40 percent by weight ethylene, a recovery stream containing by weight about 60 percent ethylene, l0 percent ethane and 30 percent propane, propylene, and heavier hydrocarbons may typically be obtained in line 53.

Economy in the process is realized through the use of the expander section 36 to drive the compressor section 35, using a portion of the rectifier 29 overhead as the expandable gas energy source. The turbo-expander is illustrative of motor devices which derive energy by gas expansion to do work and which may simultaneously cool the expanding gas. The portion of the rectifier 29 overhead passed to the expander section 36 typically comprises not less than 50 percent by volume of the rectifier overhead, and the portion passed to the com pressor accordingly less than 50 percent. The cooled and expanded overhead vapor portion e.g. at 2 l 8F is passed from expander section 36 along line ll in sequence to heat exchangers l7 and 9 where its refrigeration values are used to cool the feed as above described and ultimately to disposal as fuel gas eg at a temperature of +5 2F.

EXAMPLE To cite typical operating conditions and with reference to the table below for composition data line 1 feed at +60F and 500 psia is cooled to 1 20F at 485 psia. for entry into a first liquid-gas separator 14 with process streams and ethylene and/or propylene refrigerants. Flashed vapor from the -l 20F flash is further cooled in heat exchanger 17 to 2 lOF at 480 psia to secure a hydrogen rich by-product gas in separator 19 which is taken off along line H). Liquid from the 1 20F flash is exchanged against the feed in heat exchanger 2 and fed to the demethanizer column 22 at 75F. Demethanizer column bottom pressure is maintained at 260 psia and the temperature of material therein at $F. Overhead vapors from the demethanizer column 22 at l lF and 255 psia are rectified in rectifier 29. Rectifier overhead vapors at l65F and 250 psia are first heated in exchanger 46 to l47F and then split and less than 50 percent is passed to the intake of compressor 36 to be compressed to 500 psia at -60F. The energy for the compression is obtained from the expansion in expander 36 of the balance (greater than 50 percent) of the rectifier overhead, the expansion being from a pressure of 250 psia and a temperature of l47F to 70 psia and 2 l 8F. The expansion energy is balanced with the compression energy at these conditions. Liquid methane from separator 45 is returned to the rectifier 29 as reflux.

A typical material balance for the process is given in the tasure between about 200 and 350 psia a separation overhead of methane-rich vapor, dividing said overhead vapor into two portions, expanding a first portion of the overhead vapor through an expansion motor producing an energy output from the vapor expansion, compressing a second portion of the overhead vapor to a second pressure greater than said first pressure in a compressor driven by the energy output of said motor, cooling the compressed overhead vapor portion sufficiently to condense the major portion of the methane therein, returning the condensed methane to the methane separation zone as reflux and recovering ethylene and heavier components of the feed as bottoms from the methane separation zone.

2. Process according to claim I in which said expansion of the first overhead vapor portion is carried out to produce an energy output equal to the energy required to effect said compression of the second overhead vapor portion.

3. Process according to claim 1 in which first vapor portion comprises not less than 50 percent by volume of the methane 20 ble. separation overhead.

TABLE (molsfhour) STAGE l20 flash -21U flash [)erneth Methane anlzer Component Feed Liquid Vapor Liquid Vapor ofi-gas bottoms Hydrogen... l, 425. 00 88. 20 1,336. 80 9. 98 1, 326. 82 08. 18 C0 9. 3.19 6.41 0.89 5.52 4.08. Methane 2, B23. 38 l, 871. 752. 33 423. 42 328. ill 2, 29-1. 18 0. 29 (1 's.. 3 982.18 3, 842. 63 139. 55 136. 47 3. 08 27. (i8 3, 9M. 42 (3 's.. 668.41 666.15 2% 2.26 668.41 (-l'S+ 238. 42 218.41 0.01 0.1 238. 42

Total 8,946. 99 6, 709. 63 2, 237. 36 573. 03 1, 664. 33 2 424. 12 4,858. 54

In summary and in its preferred form the present process for the removal of methane from a hydrocarbon feed containing ethylene, hydrogen, methane and higher boiling hydrocarbon components with low low of ethylene includes removing hydrogen from the feed, fractionating the hydrogen-lean feed in a column having a bottoms temperature less than about IOF and a bottoms pressure between 250 and 275 psia to provide a methane-rich overhead vapor comprising methane and up to 4 percent by volume hydrogen, and not more than 2 percent by volume ethylene at a temperature below about l40F and a bottoms stream essentially free of methane, dividing said overhead vapor into a first portion equal to not less than 50 percent by volume of the column overhead vapor and a second portion conversely equal to less than 50 percent of the overhead vapor, expanding the first portion through a turbine to lower the pressure of the first portion to less than about 150 psia and to lower the temperature of the first portion to less than about -200F and producing an energy output from the vapor expansion, heat exchanging the expanded first portion with the feed to cool the feed to temperatures about l'F and a portion of the feed to 200"F or lower suitable for removal of hydrogen therefrom, and recovering the heat exchanged expanded first portion as fuel gas; compressing the second portion of the overhead vapor to a pressure greater than about 450 psia in a compressor driven by the energy output of the turbine, cooling the compressed second vapor portion to a temperature less than about l 35F at which at least 50 to 95 percent by weight of the methane therein condenses, separating condensed methane from the compressed second vapor portion and returning the condensed methane to the column as reflux; and recovering ethylene and higher boiling hydrocarbons as bottom from said column.

We Claim:

1. Process for the removal of methane from a hydroca'bon feed containing ethylene, methane and higher boiling hydrocarbon components with low loss of ethylene which includes effecting in a methane separation zone at a first prea- 4. Process according to claim I in which said second portion of the overhead vapor is compressed to a pressure above about 450 psia.

5. Process according to claim I in which said first portion of the overhead vapor is expanded to a pressure less than about l 50 psia.

6. Process according to claim 5 in which said second vapor portion is compressed to a pressure above about 450 psia and is thereafler cooled by external refrigeration to a temperature below about -l35F to effect liquefaction of from 50 to percent of the methane in said portion.

7. Process according to claim 6 including also returning the liquid methane obtained from said second vapor portion to the methane separation zone as reflux.

8. Process according to claim 7 in which said first vapor portion comprises not less than 50 percent by volume of the methane separation zone overhead.

9. Proces according to claim 8 and including also compressing said second vapor portion sufficiently to utilize the energy output of the expansion.

10. Process according to claim I including also centrifugally expanding said first vapor portion through a turbine.

ll. Process according to claim 9 including also centrifugally expanding said first vapor portion through a turbine.

12. Process according to claim I] including also cooling the compressed second vapor portion to a temperature liq uefying the methane therein.

13. Process according to claim I in which said feed contains hydrogen and including also flashing hydrogen and methane from said feed in advance of said methane separation zone and heat exchanging the flash vapor and flash liquid with incoming feed to cool the feed before flashing hydrogen and methane therefrom.

14. Process according to claim 13 including also heat exchanging said expanded overhead vapor portion with said feed to cool said feed prior to said flashing.

l5. Process according to claim 13 including also heat exchanging the bottoms from the methane separation zone with said feed to cool the feed prior to said flashing.

16. Process for the removal of methane from a hydrocarbon feed containing ethylene, hydrogen, methane and higher boiling hydrocarbon components with low loss of ethylene which includes hydrogen removal from the feed, fractionating said feed in a column having a bottoms temperature less than about 10F and a bottoms pressure between 250 and 275 psia to provide a methane-rich overhead vapor comprising methane, up to 4 percent by volume hydrogen and not more then 2 percent by volume ethylene at a temperature below about I40F and a bottoms stream essentially free of methane; dividing said overhead vapor into a first portion equal to not less than 50 percent by volume of said overhead vapor and a second portion conversely equal to less than 50 percent of said overhead vapor; expanding said first portion through a turbine to lower the pressure of said first portion to less than about 150 psia and to lower the temperature of said first portion to less than about 200F producing an energy output from said vapor expansion, heat exchanging said expanded first portion with said feed to cool the feed to temperature about l20F and a portion of the feed to 200F or lower suitable for hydrogen removal therefrom, and recovering the heat exchanged expanded first portion as fuel gas; compressing the second portion of the overhead vapor to a pressure greater than about 450 psia. in a compressor driven by said energy output of said turbine, cooling said compressed second vapor portion to a temperature less than about 35F at which at least 50 to percent by weight of the methane therein condenses separating condensed methane from the compressed second vapor portion and returning the condensed methane to the column as reflux; and recovering ethylene and higher boiling hydrocarbons as bottoms from said column.

Q U i I

Claims

2. Process according to claim 1 in which said expansion of the first overhead vapor portion is carried out to produce an energy output equal to the energy required to effect said compression of the second overhead vapor portion.
3. Process according to claim 1 in which first vapor portion comprises not less than 50 percent by volume of the methane separation overhead.
4. Process according to claim 1 in which said second portion of the overhead vapor is compressed to a pressure above about 450 psia.
5. Process according to claim 1 in which said first portion of the overhead vapor is expanded to a pressure less than about 150 psia.
6. Process according to claim 5 in which said second vapor portion is compressed to a pressure above about 450 psia and is thereafter cooled by external refrigeration to a temperature below about -135*F to effect liquefaction of from 50 to 95 percent of the methane in said portion.
7. Process according to claim 6 including also returning the liquid methane obtained from said second vapor portion to the methane separation zone as reflux.
8. Process according to claim 7 in which said first vapor portion comprises not less than 50 percent by volume of the methane separation zone overhead.
9. Process accordinG to claim 8 and including also compressing said second vapor portion sufficiently to utilize the energy output of the expansion.
10. Process according to claim 1 including also centrifugally expanding said first vapor portion through a turbine.
11. Process according to claim 9 including also centrifugally expanding said first vapor portion through a turbine.
12. Process according to claim 11 including also cooling the compressed second vapor portion to a temperature liquefying the methane therein.
13. Process according to claim 1 in which said feed contains hydrogen and including also flashing hydrogen and methane from said feed in advance of said methane separation zone and heat exchanging the flash vapor and flash liquid with incoming feed to cool the feed before flashing hydrogen and methane therefrom.
14. Process according to claim 13 including also heat exchanging said expanded overhead vapor portion with said feed to cool said feed prior to said flashing.
15. Process according to claim 13 including also heat exchanging the bottoms from the methane separation zone with said feed to cool the feed prior to said flashing.
16. Process for the removal of methane from a hydrocarbon feed containing ethylene, hydrogen, methane and higher boiling hydrocarbon components with low loss of ethylene which includes hydrogen removal from the feed, fractionating said feed in a column having a bottoms temperature less than about 10*F and a bottoms pressure between 250 and 275 psia to provide a methane-rich overhead vapor comprising methane, up to 4 percent by volume hydrogen and not more then 2 percent by volume ethylene at a temperature below about -140*F and a bottoms stream essentially free of methane; dividing said overhead vapor into a first portion equal to not less than 50 percent by volume of said overhead vapor and a second portion conversely equal to less than 50 percent of said overhead vapor; expanding said first portion through a turbine to lower the pressure of said first portion to less than about 150 psia and to lower the temperature of said first portion to less than about -200*F producing an energy output from said vapor expansion, heat exchanging said expanded first portion with said feed to cool the feed to temperature about -120*F and a portion of the feed to -200*F or lower suitable for hydrogen removal therefrom, and recovering the heat exchanged expanded first portion as fuel gas; compressing the second portion of the overhead vapor to a pressure greater than about 450 psia. in a compressor driven by said energy output of said turbine, cooling said compressed second vapor portion to a temperature less than about -135*F at which at least 50 to 95 percent by weight of the methane therein condenses separating condensed methane from the compressed second vapor portion and returning the condensed methane to the column as reflux; and recovering ethylene and higher boiling hydrocarbons as bottoms from said column.