Process for recovering valuables from vent gas in polyolefin production

Abstract

A process for recovering valuables from vent gas in polyolefin production is disclosed. The process includes a compression cooling separation step, a heavy hydrocarbon separation step, a light hydrocarbon separation step, a N.sub.2 purification step, and a turbo expansion step in sequence. The N.sub.2 purification step comprises a membrane separation procedure. The light hydrocarbon separation step comprises at least one gas-liquid separation procedure. A first gas, which is obtained by the gas-liquid separation procedure and is heated through heat exchange with multiple streams in the light hydrocarbon separation step, enters the heavy hydrocarbon separation step and is further heated; the heated first gas then enters the N.sub.2 purification step; a first generated gas, which is obtained by the membrane separation procedure of the N.sub.2 purification step, enters the heavy hydrocarbon separation step and the light hydrocarbon separation step in sequence, and is cooled through heat exchange with multiple streams in the heavy hydrocarbon separation step and the light hydrocarbon separation step; and then the cooled first generated gas enters the turbo expansion step. The energy consumption of a compressor can be greatly reduced. An external cooling medium with a temperature lower than an ambient temperature is not needed. The purity and recovery of N.sub.2 and hydrocarbons can be improved, which can facilitate reduction of energy consumption of a whole system, an investment, and a material consumption.

Claims

1. A process for recovering valuables from vent gas in polyolefin production, comprising a compression cooling separation step, a heavy hydrocarbon separation step, a light hydrocarbon separation step, a N.sub.2 purification step, and a turbo expansion step in sequence, wherein the N.sub.2 purification step comprises a membrane separation procedure; and wherein the light hydrocarbon separation step comprises at least one gas-liquid separation procedure; wherein a first gas, which is obtained by the gas-liquid separation procedure and is heated through heat exchange with multiple streams in the light hydrocarbon separation step, enters the heavy hydrocarbon separation step and is further heated; the heated first gas then enters the N.sub.2 purification step; a first generated gas, which is obtained by the membrane separation procedure of the N.sub.2 purification step, enters the heavy hydrocarbon separation step and the light hydrocarbon separation step in sequence, and is cooled through heat exchange with multiple streams in the heavy hydrocarbon separation step and the light hydrocarbon separation step; and then the cooled first generated gas enters the turbo expansion step.

2. The process according to claim 1, wherein an external cooling medium is used for cooling in at least one of the compression cooling separation step, the heavy hydrocarbon separation step, the light hydrocarbon separation step, the N.sub.2 purification step, and the turbo expansion step, wherein a temperature of the external cooling medium is higher than or equal to an ambient temperature.

3. The process according to claim 1, wherein in the compression cooling separation step, a vent gas and a recycle stream enter into a compressor to be compressed, and enter into a cooler, a cooling medium of which is cooling water or air.

4. The process according to claim 1, wherein in the heavy hydrocarbon separation step, a first vent gas, which is generated by the compression cooling separation step, enters into a first multi-stream heat exchanger; and wherein the first vent gas, after being cooled to a heavy hydrocarbon separation temperature, enters into at least one first gas-liquid separator in which heavy hydrocarbon and a second vent gas are separated.

5. The process according to claim 4, wherein the first multi-stream heat exchanger is a plate-fin heat exchanger, a coil-wound heat exchanger, or a combination thereof.

6. The process according to claim 1, wherein in the light hydrocarbon separation step, a second vent gas, which is generated by the heavy hydrocarbon separation step, enters into a second multi-stream heat exchanger; and wherein the second vent gas, after being cooled to a light hydrocarbon separation temperature, enters into at least one second gas-liquid separator in which light hydrocarbon is separated.

7. The process according to claim 6, wherein the second multi-stream heat exchanger is a plate-fin heat exchanger, a coil-wound heat exchanger, or a combination thereof.

8. The process according to claim 3, wherein a second generated gas, which is generated by the membrane separation procedure, is returned to an inlet of the compressor of the compression cooling separation step, or to a waste gas buffer tank; and wherein in the membrane separation procedure, at least one group of hydrocarbon selective membrane module and/or at least one group of hydrogen selective membrane module are/is used.

9. The process according to claim 8, wherein in the membrane separation procedure, one group of hydrocarbon selective membrane module and one group of hydrogen selective membrane module are used; and wherein the first gas enters into the hydrocarbon selective membrane module and the hydrogen selective membrane module in sequence, or, the first gas enters into the hydrogen selective membrane module and the hydrocarbon selective membrane module in sequence.

10. The process according to claim 1, wherein after the compression cooling separation step, the vent gas first enters into a dryer to remove water, and then enters the heavy hydrocarbon separation step.

Description

BRIEF DESCRIPTION OF THE DRAWINGS

(1) The drawings described herein are used for illustrating, rather than restricting the present disclosure. The shapes and scales of each of the components in the drawings are only exemplary ones to facilitate understanding of the present disclosure, rather than specific definition on the shapes and scales thereof. Under the teaching of the present disclosure, those skilled in the art can select any shapes and scales of the components to implement the present disclosure.

(2) FIG. 1 schematically shows a process (I) for recovering valuables from vent gas in polyolefin production according to the present disclosure;

(3) FIG. 2 schematically shows a process (II) for recovering valuables from vent gas in polyolefin production according to the present disclosure; and

(4) FIG. 3 schematically shows a process (III) for recovering valuables from vent gas in polyolefin production according to the present disclosure.

(5) In the drawings, the same components are represented by the same reference signs, and the size of each component does not represent the actual size of the corresponding component.

DETAILED DESCRIPTION OF THE EMBODIMENTS

(6) The details of the present disclosure can be understood more clearly combining the description on the drawings and the embodiments. However, the specific embodiments disclosed herein are only used for illustrating the present disclosure, while cannot be understood as limiting the present disclosure in any manner. Those skilled in the art can make any deformations under the teaching of the technical content disclosed herein, and all the deformations fall into the scope of the present disclosure. The present disclosure will be further illustrated hereinafter with reference to the drawings.

(7) FIGS. 1 to 3 respectively show a process (I) for recovering valuables from vent gas in polyolefin production, a process (II) for recovering valuables from vent gas in polyolefin production, and a process (III) for recovering valuables from vent gas in polyolefin production.

(8) It should be noted that, in the present disclosure, light hydrocarbon refers to C.sub.2H.sub.n and C.sub.3H.sub.n, and heavy hydrocarbon refers to C.sub.4+H.sub.n. As shown in FIGS. 1 to 3, the process for recovering valuables from vent gas in polyolefin production comprises a compression cooling separation step 1, a heavy hydrocarbon separation step 2, a light hydrocarbon separation step 3, a N.sub.2 purification step 4, and a turbo expansion step 5 in sequence. The N.sub.2 purification step 4 comprises a membrane separation procedure. The light hydrocarbon separation step 3 comprises at least one gas-liquid separation procedure. A first gas 33, which is obtained by the gas-liquid separation procedure, after temperature rise through heat exchange with multiple streams in the light hydrocarbon separation step 3, enters the heavy hydrocarbon separation step 2 for further temperature rise. The first gas 33, after temperature rise, enters the N.sub.2 purification step 4. A first generated gas, which is obtained by the membrane separation procedure of the N.sub.2 purification step 4, enters the heavy hydrocarbon separation step 2 and the light hydrocarbon separation step 3 in sequence, and a temperature of the first generated gas decreases after heat exchange with streams in the heavy hydrocarbon separation step and the light hydrocarbon separation step. The first generated gas, after temperature drop, enters the turbo expansion step 5.

(9) Specifically, in the compression cooling separation step 1, a vent gas 101 and a recycle stream enter into a compressor 12 to be compressed (an outlet pressure of the compressor 12 is in a range from 0.8 MPa to 2.5 MPa), and enter into a cooler 13 to be cooled. According to a specific embodiment, a cooling medium of the cooler 13 is cooling water or air.

(10) Further, after the compression cooling separation step 1, the vent gas 101 first enters into a dryer (not shown in FIGS. 1 to 3) to remove water, and then enters the heavy hydrocarbon separation step 2. A drying effect of the dryer should ensure that ice blockage would not occur in the following light hydrocarbon separation step 3. At a low-temperature environment, when the vent gas 101 contains a small amount of water, the ice blockage would possibly occur. Since the dryer is provided, the ice blockage can be prevented.

(11) Further, according to the present disclosure, the vent gas coming from the cooler 13 first passes through a waste gas buffer tank 14 and then enters the heavy hydrocarbon separation step 2. In this manner, it can be ensured that the gas is transmitted to the heavy hydrocarbon separation step 2 stably. Of course, an outlet of the waste gas buffer tank 14 can be connected to a heavy hydrocarbon recovery device 32 so as to recover heavy hydrocarbon initially. According to one specific embodiment, a dryer (not shown in FIGS. 1 to 3) is provided between the cooler 13 and the waste gas buffer tank 14. A drying effect of the dryer should ensure that ice blockage would not occur in the following light hydrocarbon separation step 3. At a low-temperature environment, when the vent gas 101 contains a small amount of water, the ice blockage would possibly occur. Since the dryer is provided, the ice blockage can be prevented.

(12) The vent gas 101 can be compressed by the compressor 12 to a certain pressure (for example 0.8 MPa to 2.5 MPa). Then, the vent gas 101 can be cooled by cooling water or air to a temperature (for example 40 C.) slightly higher than an ambient temperature. If the vent gas 101 contains a small amount of water, a dryer can be provided to remove the water so as to prevent the ice blockage.

(13) Specifically, in the heavy hydrocarbon separation step 2, a first vent gas 15, which is generated by the compression cooling separation step 1, enters into a first multi-stream heat exchanger 21. The first vent gas 15, after a temperature thereof is decreased to a heavy hydrocarbon separation temperature, enters into at least one first gas-liquid separator 22 in which heavy hydrocarbon is separated. A second vent gas 23 generated from a top of the first gas-liquid separator 22 enters the light hydrocarbon separation step 3, and heavy hydrocarbon separated from a bottom of the first gas-liquid separator 22, after being heated by the first multi-stream heat exchanger 21, enters into the heavy hydrocarbon recovery device 32 to recover heavy hydrocarbon.

(14) Further, the first multi-stream heat exchanger 21 is a plate-fin heat exchanger, a coil-wound heat exchanger, or a combination thereof. Of course, the first multi-stream heat exchanger 21 can be substituted by a plurality of common heat exchangers.

(15) A stream (i.e., a first vent gas 15) coming from the compression cooling separation step 1 enters into the first multi-stream heat exchanger 21. Heavy hydrocarbon is separated by the first gas-liquid separator 22 taking advantage of an external refrigerant provided in the following turbo expansion step 5. A liquid-phase stream, after throttling flash evaporation, is returned to the first multi-stream heat exchanger 21 to be heated. A separation temperature depends on a partial pressure, a boiling point, and a recovery of heavy hydrocarbon, and a recommended separation temperature is in a range from 20 C. to 70 C. Since heavy hydrocarbon is separated in this step, the ice blockage of heavy hydrocarbon in the following light hydrocarbon separation step can be alleviated.

(16) Specifically, in the light hydrocarbon separation step 3, a second vent gas 23, which is generated by the heavy hydrocarbon separation step 2, enters into a second multi-stream heat exchanger 31. The second vent gas 23, after a temperature thereof is decreased to a light hydrocarbon separation temperature, enters into at least one second gas-liquid separator 32 in which light hydrocarbon is separated.

(17) Further, the second multi-stream heat exchanger 31 is a plate-fin heat exchanger, a coil-wound heat exchanger, or a combination thereof. Of course, the second multi-stream heat exchanger 31 can be substituted by a plurality of common heat exchangers.

(18) A stream (i.e., a second vent gas 23) coming from a top of the first gas-liquid separator 22 enters into the second multi-stream heat exchanger 31. Light hydrocarbon is separated by the second gas-liquid separator 32 taking advantage of an external refrigerant provided in the following turbo expansion step 5. A liquid-phase stream that is separated from a bottom of the second gas-liquid separator 32, after throttling flash evaporation, is returned to the second multi-stream heat exchanger 31 and the first multi-stream heat exchanger 21 in sequence to be heated, and enters into a light hydrocarbon recovery device 36 to recover light hydrocarbon. A gas 33 (i.e., a first gas 33) coming from a top of the second gas-liquid separator 32, is returned to the second multi-stream heat exchanger 31 and the first multi-stream heat exchanger 21 in sequence to be heated. That is, the first gas 33, which is obtained by the gas-liquid separation procedure, after temperature rise through heat exchange with multiple streams in the light hydrocarbon separation step 3, enters the heavy hydrocarbon separation step 2 for further temperature rise. The first gas 33, after temperature rise, enters the N.sub.2 purification step 4. A separation temperature of the second gas-liquid separator 32 depends on a partial pressure, a boiling point, and a recovery of light hydrocarbon, and a recommended separation temperature is in a range from 90 C. to 140 C.

(19) Further, as shown in FIG. 3, a liquid-phase stream separated from the second gas-liquid separator 32 enters into a third gas-liquid separator 161, a fourth gas-liquid separator 162, and the light hydrocarbon recovery device 36 in sequence. A gas coming from a top of the third gas-liquid separator 161 is returned to the compressor 12, and a liquid-phase stream separated from the third gas-liquid separator 161 enters into the second multi-stream heat exchanger 31, the first multi-stream heat exchanger 21, and the fourth gas-liquid separator 162 in sequence. A gas coming from a top of the fourth gas-liquid separator 162 enters into the light hydrocarbon recovery device 36, and a liquid-phase stream separated from the fourth gas-liquid separator 162 is returned to the compressor 12. In this manner, the purity of the recovered light hydrocarbon can be further improved.

(20) Specifically, according to the present disclosure, a first generated gas 41 (which can be also called as residual gas 41), which is obtained by the membrane separation procedure of the N.sub.2 purification step 4, enters into the first multi-stream heat exchanger 21 and the second multi-stream heat exchanger 31 in sequence, so that a temperature of the first generated gas 41 decreases after heat exchange with streams in the heavy hydrocarbon separation step 2 and the light hydrocarbon separation step 3. The first generated gas 41, after temperature drop, enters the turbo expansion step 5. A second generated gas 42, which is generated by the membrane separation procedure of the N.sub.2 purification step 4, is returned to the compressor 12 of the compression cooling separation step 1, so that gas can be fully recovered and reused. According to the present disclosure, the membrane separation procedure comprises at least one group of hydrocarbon selective membrane module 43 and/or at least one group of hydrogen selective membrane module 44.

(21) According to one specific embodiment, the membrane separation procedure comprises one group of hydrocarbon selective membrane module 43 and one group of hydrogen selective membrane module 44. The first gas 33 enters into the hydrocarbon selective membrane module 43 and the hydrogen selective membrane module 44 in sequence, or, the first gas 33 can also enter into the hydrogen selective membrane module 44 and the hydrocarbon selective membrane module 43 in sequence. That is, a sequence of the hydrocarbon selective membrane module 43 and the hydrogen selective membrane module 44 can be adjusted. The hydrocarbon selective membrane module 43 can be arranged as a first one, or the hydrogen selective membrane module 44 can be arranged as a first one, which is not defined here.

(22) The hydrocarbon selective membrane module 43 comprises a hydrocarbon selective membrane. According to the present disclosure, the hydrocarbon selective membrane is one kind of membrane which is more permeable to hydrocarbon components than to H.sub.2, N.sub.2 and other components. A rubber polymer membrane can be selected, such as an organic siloxane polymer membrane, through which the permeation rate of hydrocarbon components is higher than that of H.sub.2, N.sub.2 and other gases. The hydrogen selective membrane module 44 comprises a hydrogen selective membrane. According to the present disclosure, the hydrogen selective membrane is one kind of membrane which is more permeable to H.sub.2 than to N.sub.2 and hydrocarbon components. A glass polymer membrane can be selected, such as polyimide membrane, polyaramide membrane, and polysulfone membrane, through which the permeation rate of H.sub.2 is higher than that of N.sub.2, hydrocarbon and other gases. The hydrocarbon selective membrane module 43 and the hydrogen selective membrane module 44 can be any one selected from a group consisting of a spiral-wound membrane module, a plate-frame membrane module, and a hollow fiber membrane module.

(23) According to one specific embodiment, a permeate gas 441 of the hydrogen selective membrane module 44 is connected to a waste gas buffer tank 10. A permeate gas 431 of the hydrocarbon selective membrane module 43 can be connected to the waste gas buffer tank 10 (as shown in FIG. 2), or connected to an inlet of the compressor 12 (as shown in FIG. 1 or FIG. 3). When the permeate gas 431 is connected to the waste gas buffer tank 10, energy consumption of the compressor 12 can be reduced, while hydrocarbon loss will be increased to some extent. When the permeate gas 431 is connected to the inlet of the compressor 12, the hydrocarbon loss will be reduced, while the energy consumption of the compressor 12 will be increased. If the permeate gas 431 contains a high amount of hydrocarbon, the permeate gas 431 can be connected to the compressor 12. If the permeate gas 431 contains a low amount of hydrocarbon, the permeate gas 431 can be connected to the waste gas buffer tank 10. That is, the permeate gas 431 can be connected to the waste gas buffer tank 10 or the compressor 12 according to actual needs.

(24) A residual gas 432 of the hydrocarbon selective membrane module 43 enters into the hydrogen selective membrane module 44, and a residual gas 442 of the hydrogen selective membrane module 44 is the first generated gas 41 obtained by the membrane separation procedure of the N.sub.2 purification step 4.

(25) The first gas 33, after being heated again, enters a hydrocarbon selective membrane separation procedure. After hydrocarbon selective membrane separation procedure, the permeate gas 431 (which mainly contains hydrocarbons) is returned to the inlet of the compressor 12, and the residual gas 432 enters a hydrogen selective membrane separation procedure. After the hydrogen selective membrane separation procedure, the permeate gas 441 is return to the waste gas buffer tank 10, and the residual gas 442 (which is mainly N.sub.2 with a high purity) enters the heavy hydrocarbon separation step 2 and the light hydrocarbon separation step 1 in sequence to be cooled. Specifically, according to the present disclosure, the residual gas 442 enters into the first multi-stream heat exchanger 21 and the second multi-stream heat exchanger 31 in sequence to be cooled. If the residual gas after the hydrocarbon selective membrane separation procedure enters the hydrogen selective membrane separation procedure, the permeate gas of the hydrogen selective membrane should be discharged outside the system due to H.sub.2 accumulation. That is, the permeate gas 441 is returned to the waste gas buffer tank 10.

(26) The first generated gas 41 is returned to the heavy hydrocarbon separation step 2 and the light hydrocarbon separation step 3 to be cooled, and enters into a turbine expander 51 of a following turbo expansion step 5 to be expanded. The expanded gas is returned to the light hydrocarbon separation step 3 and the heavy hydrocarbon separation step 2 to serve as a low-temperature external refrigerant, so that a cold energy of the gas can be fully utilized, which can facilitate the reduction of energy consumption. Then, the gas enters into a N.sub.2 recovery device 6.

(27) Further, according to the present disclosure, at least one of the compression cooling separation step 1, the heavy hydrocarbon separation step 2, the light hydrocarbon separation step 3, the N.sub.2 purification step 4, and the turbo expansion step 5 is cooled by an external cooling medium. A temperature of the external cooling medium is higher than or equal to an ambient temperature, which can facilitate the reduction of energy consumption.

(28) According to one specific embodiment, only the compression cooling separation step 1 is cooled by an external cooling medium, while other steps are not cooled by an external cooling medium.

(29) Of course, according to the present disclosure, it can be arranged that the compression cooling separation step 1, the heavy hydrocarbon separation step 2, the light hydrocarbon separation step 3, the N.sub.2 purification step 4, and the turbo expansion step 5 each are not cooled by an external cooling medium.

(30) According to the present disclosure, the low-temperature cold energy in the heavy hydrocarbon separation step 2 and the light hydrocarbon separation step 3 completely comes from an expansion cold energy in the turbo expansion step 5, and an external cooling medium with a temperature no lower than an ambient temperature (i.e., the temperature of the external cooling medium is higher than or equal to the ambient temperature) is used only in the compression cooling separation step 1. By contrast, as to other methods, an external low-temperature cooling medium should be used to obtain same purity and recovery of hydrocarbon and N.sub.2.

(31) According to the present disclosure, a hydrocarbon separation process comprises the heavy hydrocarbon separation step 2 and the light hydrocarbon separation step 3 to achieve following purposes: first, to separate heavy hydrocarbon from light hydrocarbon; and second, to prevent ice blockage of heavy hydrocarbon in the light hydrocarbon separation step 3.

(32) It should be noted that, if the vent gas contains a small amount of heavy hydrocarbon, the ice blockage of heavy hydrocarbon would not occur in the light hydrocarbon separation step 3, and it is unnecessary to separate heavy hydrocarbon from light hydrocarbon, the heavy hydrocarbon separation step 2 can be omitted. That is, according to the present disclosure, the heavy hydrocarbon separation step 2 can be omitted, and thus the light hydrocarbon separation step 3 can be called as a hydrocarbon separation step.

(33) It should be further noted that, as shown in FIG. 2, the permeate gas 431 of the hydrocarbon selective membrane is directly discharged outside the system, and is not returned to the compressor 12. In this manner, the energy consumption of the compressor 12 can be reduced, while the hydrocarbon loss will be increased. As shown in FIG. 3, a liquid-phase stream coming from a bottom of the second gas-liquid separator 32 is throttled by a throttle valve 160, and enters the third gas-liquid separator 161 (which can also be called as a flash evaporation tank) to separate gas from liquid. The gas is returned to the compressor 12. The liquid enters into the second multi-stream heat exchanger 31 and the first multi-stream heat exchanger 21 in sequence to be heated, and then enters into the fourth gas-liquid separator 162 for further gas-liquid separation. A gas coming from a top of the fourth gas-liquid separator 162 enters into the light hydrocarbon recovery device 36, and a liquid separated by the fourth gas-liquid separator 162 is returned to the compressor 12. In this manner, the purity of the recovered light hydrocarbon can be further improved.

(34) According to the present disclosure, a recovery stream refers to a stream that is returned to the compressor 12 from the heavy hydrocarbon separation step 2, the light hydrocarbon separation step 3, and the N.sub.2 purification step 4.

(35) As shown in FIGS. 1 to 3, in the first multi-stream heat exchanger 21 and the second multi-stream heat exchanger 31, a stream from a left side to a right side is a temperature drop procedure, while a stream from the right side to the left side is a temperature rise procedure. According to the present disclosure, a gas-phase outlet of a gas-liquid separator is provided at a top of the tank, and a liquid-phase outlet of the gas-liquid separator is provided at a bottom of the tank.

(36) The process for recovering valuables from vent gas in polyolefin production provided herein is used in an actual system, and the system is compared with a traditional system.

EXAMPLE 1

(37) A vent gas of a high-pressure condenser in a polyethylene plant of a petrochemical enterprise has a temperature of 10 C., and a pressure of 1.2 MPa. Since the vent gas has a certain pressure, no compressor is provided. The method as shown in FIG. 3 is used. In order to highlight an importance of separation sequence, comparative example 1 adopts the method of CN201310444283, and the method comprises a compression cooling separation step, a hydrogen selective membrane separation step, a heavy hydrocarbon separation step, and a light hydrocarbon separation step. The results of example 1 and comparative example 1 are shown in Table 1.

(38) Comparing the results of example 1 and comparative example 1, and the comparative results are shown in Table 2.

(39) TABLE-US-00001 TABLE 1 Results of example 1 and comparative example 1 Vent High-pressure Cryogenic Recovered light Recovered heavy Recovered Waste gas condensate gas hydrocarbon hydrocarbon N.sub.2 gas Comparative example 1 Mass Flow (kg/hr) H.sub.2 7.012 0.021 6.991 0.002 0.001 2.867 4.122 Methane 8.416 0.194 8.222 0.184 0.043 7.055 0.939 N.sub.2 1845.028 9.331 1835.697 4.620 1.359 1649.967 179.750 Ethylene 325.583 33.699 291.884 82.696 13.115 172.527 23.545 Ethane 77.048 11.937 65.111 27.717 5.232 27.300 4.863 Isopentane 1446.013 1322.013 124.000 5.151 116.995 0.004 1.850 Mass Frac (%) H.sub.2 0.19 0.00 0.30 0.00 0.00 0.15 1.92 Methane 0.23 0.01 0.35 0.15 0.03 0.38 0.44 N.sub.2 49.74 0.68 78.72 3.84 0.99 88.72 83.58 Ethylene 8.78 2.45 12.52 68.70 9.59 9.28 10.95 Ethane 2.08 0.87 2.79 23.03 3.83 1.47 2.26 Isopentane 38.99 95.99 5.32 4.28 85.56 0.00 0.86 Molar flow (kmol/hr) 104.07 20.28 83.80 4.12 2.31 67.82 9.55 Mass flow (kg/hr) 3709.10 1377.20 2331.91 120.37 136.74 1859.72 215.07 Temperature ( C.) 42 10 10 41.9 60 41.9 10 Pressure (bar) 1.16 13 13 1.5 13 1.5 1.5 Example 1 Mass Flow (kg/hr) H.sub.2 7.012 0.024 9.724 0.000 0.003 2.859 4.126 Methane 8.416 0.292 15.072 0.935 0.078 6.350 0.760 N.sub.2 1845.028 9.097 2183.067 1.701 1.547 1665.071 167.612 Ethylene 325.583 32.522 343.217 252.305 14.692 24.105 1.959 Ethane 77.048 10.720 71.237 58.170 5.450 2.520 0.188 Isopentane 1446.013 1302.558 148.651 1.910 141.545 0.000 0.000 Mass Frac (%) H.sub.2 0.19 0.00 0.35 0.00 0.00 0.17 2.36 Methane 0.23 0.02 0.54 0.30 0.05 0.37 0.44 N.sub.2 49.74 0.67 78.78 0.54 0.95 97.89 95.97 Ethylene 8.78 2.40 12.39 80.09 9.00 1.42 1.12 Ethane 2.08 0.79 2.57 18.47 3.34 0.15 0.11 Isopentane 38.99 96.11 5.36 0.61 86.67 0.00 0.00 Molar flow (kmol/hr) 104.07 19.92 100.36 11.07 2.73 62.20 8.15 Mass flow (kg/hr) 3709.10 1355.21 2770.97 315.02 163.31 1700.91 174.65 Temperature ( C.) 42 10 10 12.4 60 12.4 15 Pressure (bar) 1.16 13 13 1.5 13 2 1.5

(40) TABLE-US-00002 TABLE 2 Comparative results Mass Light Hydrocarbon N.sub.2 N.sub.2 flow of hydrocarbon recovery purity recovery waste gas purity (%) (%) (%) (%) (kg/h) Comparative 91.73 98.36 88.72 90.26 215.07 example 1 Example 1 98.56 99.88 97.89 90.91 174.65

(41) According to the present example, the vent gas of polyethylene plant is recovered. It can be seen from Table 2 that, under a condition that no energy consumption is increased, all performances in example 1 are better than those in comparative example 1. In particular, the N.sub.2 purity and light hydrocarbon purity in example 1 are much higher than those in comparative example 1. Therefore, it is shown that different separation sequence will bring about absolutely different separation effect.

EXAMPLE 2

(42) A vent gas from a polypropylene plant of an enterprise has a temperature of 42 C., and a pressure of 1.16 barA before entering into the compressor. The method as shown in FIG. 3 is used. Comparative example 2 adopts the method of CN201310444283, and the method comprises a compression cooling separation step, a hydrogen selective membrane separation step, a heavy hydrocarbon separation step, and a light hydrocarbon separation step. According to the method of comparative example 2, a much lower temperature should be used to obtain a high purity N.sub.2. The method of comparative example 2 is not cost-effective in terms of investment, energy consumption, hydrocarbon purity, and N.sub.2 recovery. Here, on the premise that the energy consumption of a compressor in example 2 is the same as that in comparative example 2, other performances are compared. Results of comparative example 2 are shown in Table 3, and results of example 2 are shown in Table 4.

(43) Comparing the results in Table 3 and Table 4, and the comparative results are shown in Table 5.

(44) TABLE-US-00003 TABLE 3 Results of comparative example 2 Comparative example 2 Vent Recovered light Recovered heavy Recovered Waste gas hydrocarbon hydrocarbon N.sub.2 gas Mass flow (kg/hr) H.sub.2 1.523 0.000 0.000 0.517 1.006 Propane 413.96 365.12 28.09 1.606 19.141 Propene 22.934 19.985 1.823 0.066 1.060 Ethylene 171.539 132.701 1.725 21.998 15.116 N-hexane 24.231 1.986 21.856 0.000 0.389 N.sub.2 2316.688 1.769 0.687 2066.247 247.985 Mass Frac (%) H.sub.2 0.05 0.00 0.00 0.02 0.35 Propane 14.03 70.01 51.84 0.08 6.72 Propene 0.78 3.83 3.36 0.00 0.37 Ethylene 5.81 25.44 3.18 1.05 5.31 N-hexane 0.82 0.38 40.34 0.00 0.14 N.sub.2 78.51 0.34 1.27 98.84 87.10 Molar flow (kmol/hr) 100.21 13.95 1.05 74.84 10.37 Mass flow (kg/hr) 2950.87 521.56 54.18 2090.43 284.70 Temperature ( C.) 42 14.52 30 14.52 40.00 Pressure (bar) 1.16 1.5 18 2.8 1.5

(45) TABLE-US-00004 TABLE 4 Results of example 2 Example 2 Vent Recovered Recovered Recovered Waste gas light hydrocarbon heavy hydrocarbon N.sub.2 gas Mass flow (kg/hr) H.sub.2 1.523 0.000 0.000 0.515 1.007 Propane 413.95 396.68 16.70 0.546 0.025 Propene 22.934 21.813 1.100 0.021 0.001 Ethylene 171.54 160.21 1.151 9.346 0.833 N-hexane 24.231 1.398 22.833 0.000 0.000 N.sub.2 2316.688 2.008 0.472 2083.550 230.658 Mass Frac (%) H.sub.2 0.05 0.00 0.00 0.02 0.43 Propane 14.03 68.15 39.52 0.03 0.01 Propene 0.78 3.75 2.60 0.00 0.00 Ethylene 5.81 27.52 2.72 0.45 0.36 N-hexane 0.82 0.24 54.03 0.00 0.00 N.sub.2 78.51 0.34 1.12 99.50 99.20 Molar flow (kmol/hr) 100.21 15.72 0.74 74.98 8.76 Mass flow (kg/hr) 2950.87 582.11 42.26 2093.98 232.52 Temperature ( C.) 42 20.53 30 20.53 20.53 Pressure (bar) 1.16 1.5 18 2.8 1.5

(46) TABLE-US-00005 TABLE 5 Comparative results Mass Light flow of hydrocarbon Hydrocarbon N.sub.2 N.sub.2 waste purity recovery purity recovery gas (wt %) (wt %) (wt %) (wt %) (kg/h) Comparative 99.28 94.37 98.84 89.3 248 example 2 Example 2 99.41 99.86 99.5 90 230

(47) Under a condition that the compressors have a same energy consumption, all performances in example 2 are better than those in comparative example 2. In particular, the hydrocarbon recovery and the N.sub.2 purity are greatly improved.

EXAMPLE 3

(48) A vent gas from a polypropylene plant of an enterprise has a temperature of 40 C., and a pressure of 1.2 barA before entering into the compressor. Comparative example 3 adopts the method of U.S. Pat. No. 5,769,927. In order to facilitate comparison, a hydrogen selective membrane separation step is added to the method of U.S. Pat. No. 5,769,927, and the method comprises a compression cooling separation step, a hydrocarbon selective membrane separation step, and the hydrogen selective membrane separation step. In example 3 and comparative example 3, the obtaining of N.sub.2 with a purity of 99.5% is taken as a comparison condition. Results of comparative example 3 and example 3 are shown in Table 6.

(49) TABLE-US-00006 TABLE 6 Results of comparative example 3 and example 3 Comparative example 3 Example 3 Vent Recovered Recovered Waste Vent Recovered light Recovered heavy Recovered Waste gas hydrocarbon N.sub.2 gas gas hydrocarbon hydrocarbon N.sub.2 gas Mass flow (kg/hr) H.sub.2 1.729 0.009 0.233 1.486 1.729 0.000 0.000 0.834 0.895 Propene 636.428 625.768 9.810 0.846 636.428 610.992 14.912 10.042 0.483 Propane 15.452 15.284 0.155 0.013 15.452 14.822 0.433 0.187 0.009 N-hexane 34.079 34.079 0.000 0.000 34.079 4.140 29.939 0.000 0.000 N.sub.2 2599.60 11.71 2125.706 462.19 2599.6 1.426 0.272 2331.80 266.103 Mass Frac (%) H.sub.2 0.05 0.00 0.01 0.32 0.05 0.00 0.00 0.04 0.33 Propene 19.36 91.11 0.46 0.18 19.36 96.77 32.73 0.44 0.18 Propane 0.47 2.23 0.01 0.00 0.47 2.35 0.95 0.01 0.00 N-hexane 1.04 4.96 0.00 0.00 1.04 0.66 65.72 0.00 0.00 N.sub.2 79.08 1.70 99.52 99.50 79.08 0.23 0.60 99.52 99.48 Molar flow (kmol/hr) 10952.6 1603.5 7623.4 1725.7 10952.6 1495.5 72.1 8389.5 995.5 Mass flow (kg/hr) 3287.3 686.8 2135.9 464.5 3287.3 631.4 45.6 2342.9 267.5 Temperature ( C.) 40 30 30 30 40 38 26 38 0.00E+00 Pressure (bar) 1.2 18 18 1.5 1.2 1.5 11 1.5 1.5

(50) TABLE-US-00007 TABLE 7 Comparative results of energy consumption Compressor Condenser energy energy consumption consumption (kw) (kw) Remark Comparative 1754 1930 The condenser needs to be example 3 cooled to 30 C. by a refrigeration system Example 3 900 901 The condenser is cooled to 40 C. only by cooling water

(51) It can be seen from Table 7 that, to obtain N.sub.2 with a purity of 99.5%, a stream at an inlet of the compressor and a pressure at an outlet thereof in comparative example 3 (which comprises the compression cooling separation step, the hydrocarbon selective membrane separation step, and the hydrogen selective membrane separation step) are higher than those in example 3, and thus the energy consumption of the compressor in comparative example 3 is much higher than that in example 3. Moreover, in comparative example 3, the vent gas needs to be cooled to 30 C. by an additional external refrigerant, and then hydrocarbon can be recovered. Compared with the cooling water in example 3, energy consumption is further increased. In addition, according to comparative example 3, heavy hydrocarbon and light hydrocarbon are not separated.

(52) It can be seen from the above three examples that, in the process provided herein, the energy consumption of the compressor can be greatly reduced. In addition, an external cooling medium with a temperature lower than an ambient temperature is not needed. The purity and recovery of N.sub.2 and hydrocarbons can be improved, which can facilitate reduction of energy consumption of the whole system, the investment, and the material consumption.

(53) According to the present disclosure, the low-temperature cold energy in the heavy hydrocarbon separation step 2 and the light hydrocarbon separation step 3 completely comes from an expansion cold energy in the turbo expansion step 5, and an external cooling medium with a temperature no lower than the ambient temperature is used only in the compression cooling separation step 1. By contrast, as to other methods, an external low-temperature cooling medium should be used to obtain same purity and recovery of hydrocarbon and N.sub.2. According to the present disclosure, a hydrocarbon separation process comprises the heavy hydrocarbon separation step and the light hydrocarbon separation step to achieve following purposes: first, to separate heavy hydrocarbon from light hydrocarbon; and second, to prevent ice blockage of heavy hydrocarbon in the light hydrocarbon separation step.

(54) According to the present disclosure, the compression cooling separation step, the heavy hydrocarbon separation step, the light hydrocarbon separation step, the N.sub.2 purification step, and the turbo expansion step are arranged in sequence to form an optimized separation sequence, whereby the energy consumption of the compressor can be greatly reduced. In addition, an external cooling medium with a temperature lower than an ambient temperature is not needed. The purity and recovery of N.sub.2 and hydrocarbons can be improved, which can facilitate reduction of energy consumption of the whole system, the investment, and the material consumption.

(55) The present disclosure is illustrated in detail in combination with preferred embodiments hereinabove, but it can be understood that the embodiments disclosed herein can be improved or substituted without departing from the protection scope of the present disclosure. In particular, as long as there are no structural conflicts, the technical features disclosed in each and every embodiment of the present disclosure can be combined with one another in any way, and the combined features formed thereby are within the protection scope of the present disclosure. The present disclosure is not limited by the specific embodiments disclosed herein, but includes all technical solutions falling into the protection scope of the claims.