CN114854463B - Dehydration and hydrocarbon removal device - Google Patents
Dehydration and hydrocarbon removal device Download PDFInfo
- Publication number
- CN114854463B CN114854463B CN202110147803.XA CN202110147803A CN114854463B CN 114854463 B CN114854463 B CN 114854463B CN 202110147803 A CN202110147803 A CN 202110147803A CN 114854463 B CN114854463 B CN 114854463B
- Authority
- CN
- China
- Prior art keywords
- gas
- temperature range
- separator
- cooler
- separation unit
- Prior art date
- 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.)
- Active
Links
Images
Classifications
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
- C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
- C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
- C10L3/10—Working-up natural gas or synthetic natural gas
- C10L3/101—Removal of contaminants
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
- C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
- C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
- C10L3/10—Working-up natural gas or synthetic natural gas
- C10L3/101—Removal of contaminants
- C10L3/106—Removal of contaminants of water
Abstract
The present application provides a dehydration and hydrocarbon removal device, the device comprising: a primary separation unit, a secondary separation unit and a tertiary separation unit. The output end of the primary separation unit is connected with the input end of the secondary separation unit, and the output end of the secondary separation unit is connected with the input end of the tertiary separation unit. The primary separation unit is used for separating the raw material gas in a first temperature range to obtain first separated gas. The secondary separation unit is used for separating the first separation gas in a second temperature range to obtain a second separation gas. The third separation unit is used for separating the second separation gas at a low temperature within a third temperature range to obtain liquid hydrocarbon. Wherein the first temperature range is higher than the second temperature range, which is higher than the third temperature range, and the second temperature range is determined according to the condensation temperature of the hydrate. The light hydrocarbon product extracted from the liquid hydrocarbon meets the requirement of stabilizing the quality of the light hydrocarbon, and solves the problem that the heavy hydrocarbon content in the light hydrocarbon product exceeds the standard.
Description
Technical Field
The invention relates to the technical field of oil gas production, and provides a dehydration and hydrocarbon removal device.
Background
The dehydration and hydrocarbon removal device has the function of guaranteeing that the water dew point and the hydrocarbon dew point in the natural gas meet the requirements, and adopts the technological methods such as injection alcohol, low-temperature separation and the like to carry out dehydration and hydrocarbon removal treatment on the natural gas.
At present, a condensate gas field usually adopts a shallow cold dehydration and dealkylation process to carry out dehydration and dealkylation, and aims at purifying natural gas and controlling the dew point of the natural gas.
However, sampling the light hydrocarbon product finds that the heavy hydrocarbon content in part of the light hydrocarbons exceeds the standard, and the quality of the light hydrocarbons does not meet the national product quality standard.
Disclosure of Invention
The application provides a dehydration and dealkylation device for solve the problem that heavy hydrocarbon content exceeds standard in the light hydrocarbon product.
In a first aspect, the present application provides a dehydration and dealkylation apparatus comprising:
the primary separation unit is used for separating the raw material gas in a first temperature range to obtain a first separated gas;
the input end of the secondary separation unit is connected with the output end of the primary separation unit and is used for separating the first separation gas in a second temperature range to obtain a second separation gas;
the input end of the third separation unit is connected with the output end of the second separation unit, and is used for carrying out low-temperature separation on the second separation gas in a third temperature range to obtain liquid hydrocarbon;
wherein the first temperature range is higher than the second temperature range, and the second temperature range is higher than the third temperature range; the second temperature range is determined based on the condensation temperature of the hydrate.
Optionally, the secondary separation unit comprises:
the first cooler is used for carrying out cooling treatment on the first separated gas and outputting the first separated gas through a first output end of the first cooler so as to enable the temperature of the first separated gas to be in a second temperature range;
and the input end of the first separator is connected with the first output end of the first cooler and is used for separating the first separated gas in the second temperature range and outputting the second separated gas through the output end of the first separator.
Optionally, the tertiary separation unit comprises:
the first input end of the second cooler is connected with the output end of the first separator and is used for carrying out multistage cooling treatment on the second separated gas and outputting the second separated gas through the first output end of the second cooler so as to enable the temperature of the first separated gas to be in a third temperature range;
and the input end of the second separator is connected with the first output end of the second cooler, and is used for separating the second separated gas in the third temperature range and outputting liquid hydrocarbon through the first output end of the second separator.
Optionally, the second output end of the second separator is connected with the second input end of the second cooler, the second output end of the second cooler is connected with the second input end of the first cooler, and the second separator is further used for outputting dry gas through the second output end and performing heating treatment through the second cooler and the first cooler.
Optionally, the first cooler comprises a heat exchanger and the second cooler comprises two precoolers and a refrigeration valve.
Optionally, the first cooler comprises a precooler, and the second cooler comprises a precooler and a refrigeration valve.
Optionally, the first cooler is further preceded by a third separator for separating the first separated gas in a fourth temperature range to obtain a third separated gas;
wherein the fourth temperature range is lower than the first temperature range and higher than the second temperature range.
Alternatively, the first temperature range is 57 ℃, the second temperature range is 17 ℃ to 25 ℃, the third temperature range is-27 ℃ to-22.8 ℃, and the fourth temperature range is 40 ℃.
Optionally, the primary separation unit comprises a gas-liquid separator;
the gas-liquid separator is used for separating the raw material gas in a first temperature range to obtain first separated gas.
Optionally, the primary separation unit further comprises an air cooler;
the input end of the air cooler is connected with the output end of the gas-liquid separator and is used for carrying out cooling treatment on the first separated gas and outputting the first separated gas through the output end of the air cooler so that the temperature of the first separated gas is in a fourth temperature range.
The present application provides a dehydration and hydrocarbon removal device, the device comprising: a primary separation unit, a secondary separation unit and a tertiary separation unit. The output end of the primary separation unit is connected with the input end of the secondary separation unit, and the output end of the secondary separation unit is connected with the input end of the tertiary separation unit. The primary separation unit is used for separating the raw material gas in a first temperature range to obtain first separated gas. The secondary separation unit is used for separating the first separation gas in a second temperature range to obtain a second separation gas. The third separation unit is used for separating the second separation gas at a low temperature within a third temperature range to obtain liquid hydrocarbon. Wherein the first temperature range is higher than the second temperature range, which is higher than the third temperature range, and the second temperature range is determined according to the condensation temperature of the hydrate. The light hydrocarbon product extracted from the liquid hydrocarbon meets the requirement of stabilizing the quality of the light hydrocarbon, and solves the problem that the heavy hydrocarbon content in the light hydrocarbon product exceeds the standard.
Drawings
FIG. 1 is a schematic diagram of a dehydration and hydrocarbon removal apparatus provided in accordance with an exemplary embodiment of the present application;
FIG. 2 is a schematic diagram of a dehydration and hydrocarbon removal apparatus provided in accordance with another exemplary embodiment of the present application;
FIG. 3 is a schematic diagram of a dehydration and hydrocarbon removal apparatus provided in accordance with yet another exemplary embodiment of the present application;
FIG. 4 is a schematic diagram of a dehydration and hydrocarbon removal apparatus provided in accordance with yet another exemplary embodiment of the present application;
fig. 5 is a schematic diagram of a dehydration and hydrocarbon removal apparatus provided in accordance with yet another exemplary embodiment of the present application.
Detailed Description
For the purposes of making the objects, technical solutions and advantages of the present application more apparent, the technical solutions in the present application will be clearly and completely described below with reference to the drawings in the present application, and it is apparent that the described embodiments are some, but not all, embodiments of the present application. All other embodiments, which can be made by one of ordinary skill in the art without undue burden from the present disclosure, are within the scope of the present disclosure.
The technical scheme of the present application is described in detail below with specific examples. The following embodiments may be combined with each other, and some embodiments may not be repeated for the same or similar concepts or processes.
The dehydration and hydrocarbon removal device has the function of guaranteeing that the water dew point and the hydrocarbon dew point in the natural gas meet the requirements, and adopts the technological methods such as injection alcohol, low-temperature separation and the like to carry out dehydration and hydrocarbon removal treatment on the natural gas.
At present, a condensate gas field usually adopts a shallow cold dehydration and dealkylation process to carry out dehydration and dealkylation, and aims at purifying natural gas and controlling the dew point of the natural gas.
However, sampling the light hydrocarbon product finds that the heavy hydrocarbon content in part of the light hydrocarbons exceeds the standard, and the quality of the light hydrocarbons does not meet the national product quality standard.
The components in the light hydrocarbon are distilled under normal pressure, the normal pressure boiling point is the physical characteristic of alkane, and the carbon number increases with the increase of the carbon number, and C in single component 10 The boiling point of the catalyst is 174 ℃, and C 11 + The boiling points of the heavy hydrocarbons all exceeded 190 ℃. The national standard GB9053-2013 (stable light hydrocarbon) requires that the final distillation point of the stable light hydrocarbon is not higher than 190 ℃, or controls C in the light hydrocarbon 11 + The content of heavy hydrocarbons. The reason for disqualification of the light hydrocarbon is that the light hydrocarbon composition contains C 11 + Heavy hydrocarbons and the content exceeds the standard, so that light hydrocarbon products are disqualified.
Analyzing the reason of exceeding the standard of the heavy hydrocarbon content to find C 11 + The heavy hydrocarbons come from three streams of gas, respectively: the gas output by the secondary separation unit, the primary flash gas and the gas output by the stable gas compressor. Wherein, C in the gas output by the secondary separation unit 11 + The heavy hydrocarbon content was 0.0145mol% (700.52 kg/h), C in the first-stage flash gas 11 + The heavy hydrocarbon content was 0.0041mol% (0.3740 kg/h), stabilizing the C in the gas output from the gas compressor 11 + The heavy hydrocarbon content was 0.0028mol% (0.5431 kg/h). C in stable light hydrocarbon product obtained by dehydration and dealkylation device 11 + The heavy hydrocarbon content was 2.199mol% (700.23 kg/h). It can be seen that, of the three gases, the gas C outputted from the secondary separation unit 11 + The heavy hydrocarbon content was 99.87%. Thus, C in the secondary separation unit 11 + The heavy hydrocarbon content plays a decisive role in qualification of light hydrocarbon products and is a main control object.
In order to solve the above problems, embodiments of the present application provide a dehydration and hydrocarbon removal device, which analyzes multi-stage condensation and separation of raw gas, and finds that heavy hydrocarbon components can be further separated out when the temperature is continuously reduced to below 25 ℃, so as to ensure that light hydrocarbons are qualified. By analysis of the hydrate formation temperature of the feed gas, the hydrate formation temperature at 10.70MPa is 18.8 ℃, and the temperature at which effective separation is performed without the addition of antifreeze should be 3 to 5 ℃ higher than the hydrate formation temperature, i.e., a minimum of 22 ℃. Therefore, when no antifreezing agent is added, the optimal separation temperature range is 22-25 ℃, and at the temperature, the light hydrocarbon qualification can be met, and the addition of the antifreezing agent can be reduced to the greatest extent.
Several possible dehydration and dealkylation devices are described below to provide a clearer understanding of the technical aspects and advantages of the present application to those skilled in the art.
Fig. 1 is a schematic diagram of a dehydration and hydrocarbon removal apparatus provided in accordance with an exemplary embodiment of the present application. As shown in fig. 1, the dehydration and hydrocarbon removal device provided in this embodiment includes: primary separation unit 10, secondary separation unit 20, and tertiary separation unit 30.
The output of the primary separation unit 10 is connected to the input of the secondary separation unit 20, and the output of the secondary separation unit 20 is connected to the input of the tertiary separation unit 30.
The primary separation unit 10 inputs the raw material gas in the first temperature range to the input end of the primary separation unit 10, and the primary separation unit 10 separates the raw material gas in the first temperature range to obtain the first separated gas. The first separated gas is cooled and then outputted to the secondary separation unit 20.
The input end of the secondary separation unit 20 is input with the first separation gas, and the first separation gas is cooled to a second temperature range, wherein the first temperature range is higher than the second temperature range, and the second temperature range is determined according to the condensation temperature of the hydrate. The secondary separation unit 20 separates the first separated gas in a second temperature range to obtain a second separated gas. The second separated gas is output to the tertiary separation unit 30.
The input end of the third separation unit 30 inputs the second separation gas, and cools the second separation gas to a third temperature range, wherein the second temperature range is higher than the third temperature range. The third separation unit 30 performs low-temperature separation on the second separated gas in the third temperature range to obtain liquid hydrocarbons.
The dehydration and hydrocarbon removal device provided in this embodiment includes: a primary separation unit, a secondary separation unit and a tertiary separation unit. The output end of the primary separation unit is connected with the input end of the secondary separation unit, and the output end of the secondary separation unit is connected with the input end of the tertiary separation unit. The primary separation unit is used for separating the raw material gas in a first temperature range to obtain first separated gas. The secondary separation unit is used for separating the first separation gas in a second temperature range to obtain a second separation gas. The third separation unit is used for separating the second separation gas at a low temperature within a third temperature range to obtain liquid hydrocarbon. Wherein the first temperature range is higher than the second temperature range, which is higher than the third temperature range, and the second temperature range is determined according to the condensation temperature of the hydrate. The light hydrocarbon product extracted from the liquid hydrocarbon meets the requirement of stabilizing the quality of the light hydrocarbon, solves the problem that the content of heavy hydrocarbon in the light hydrocarbon product exceeds the standard, and eliminates the quality risk of the light hydrocarbon product.
Fig. 2 is a schematic diagram of a dehydration and hydrocarbon removal apparatus provided in accordance with another exemplary embodiment of the present application. As shown in fig. 2, the dehydration and hydrocarbon removal device provided in this embodiment includes: primary separation unit 10, first cooler 21, first separator 22, second cooler 31, and second separator 32.
The secondary separation unit includes a first cooler 21 and a first separator 22, and the tertiary separation unit includes a third separator 31 and a second separator 32.
The output of the primary separation unit 10 is connected to the input of a first cooler 21, the first output of the first cooler 21 is connected to the input of a first separator 22, the output of the first separator 22 is connected to the first input of a second cooler 31, and the first output of the second cooler 31 is connected to the input of a second separator 32.
The primary separation unit 10 inputs the raw material gas in the first temperature range to the input end of the primary separation unit 10, and the primary separation unit 10 separates the raw material gas in the first temperature range to obtain the first separated gas. The output end of the primary separation unit 10 cools the first separated gas and outputs the cooled first separated gas to the input end of the first cooler 21.
The first separated gas is input to the input end of the first cooler 21, and is cooled to a second temperature range, wherein the first temperature range is higher than the second temperature range, and the second temperature range is determined according to the condensation temperature of the hydrate. The first output end of the first cooler 21 outputs the cooled first separated gas to the input end of the first separator 22.
The first separator 22 receives the first separated gas at its input and separates the first separated gas in a second temperature range to obtain a second separated gas. The output of the first separator 22 outputs the second separated gas to the first input of the second cooler 31.
The first input end of the second cooler 31 inputs the second separated gas, performs multi-stage cooling treatment on the second separated gas, and cools the second separated gas to a third temperature range, wherein the second temperature range is higher than the third temperature range. The first output end of the second cooler 31 outputs the cooled second separated gas to the input end of the second separator 32.
The input of the second separator 32 performs cryogenic separation of the second separated gas in a third temperature range to obtain liquid hydrocarbons and dry gas. The first output of the second separator 32 outputs liquid hydrocarbons. The second output of the second separator 32 outputs dry gas.
In order to bring the temperature of the dry gas back up from the third temperature range, the second output of the second separator 32 is connected to the second input of the second cooler 31, and the second output of the second cooler 31 is connected to the second input of the first cooler 21.
The second output of the second separator 32 outputs dry gas at a third temperature range. The dry gas is input to the second input end of the second cooler 31, and after the heating treatment, the dry gas is output from the second output end of the second cooler 31. The dry gas is input to the second input end of the first cooler 21, and after the heating treatment, the dry gas is output from the second output end of the first cooler 21. The dry gas collecting device can collect dry gas.
Fig. 3 is a schematic diagram of a dehydration and hydrocarbon removal apparatus provided in accordance with yet another exemplary embodiment of the present application. As shown in fig. 3, the dehydration and hydrocarbon removal device provided in this embodiment includes: gas-liquid separator 11, air cooler 12, heat exchanger 211, first separator 22, first precooler 311, second precooler 312, refrigeration valve 313, and second separator 32.
Wherein the primary separation unit 10 includes a gas-liquid separator 11 and an air cooler 12. The first cooler 21 includes a heat exchanger 211. The second cooler 31 comprises two precoolers and a refrigeration valve, one precooler is a first precooler 311, the first precooler 311 is composed of a precooler A and a precooler B, the other precooler is a second precooler 312, the second precooler 312 is composed of a precooler C and a precooler D, and the refrigeration valve 313 is a J-T valve. The first separator 22 is a water separator and the second separator 32 is a cryogenic separator.
The output end of the gas-liquid separator 11 is connected with the input end of the air cooler 12, the output end of the air cooler 12 is connected with the first input end of the heat exchanger 211, the first output end of the heat exchanger 211 is connected with the input end of the first separator 22, the output end of the first separator 22 is connected with the first input end of the first precooler 311, the first output end of the first precooler 311 is connected with the first input end of the second precooler 312, the first output end of the second precooler 312 is connected with the input end of the refrigeration valve 313, the output end of the refrigeration valve 313 is connected with the input end of the second separator 32, and the first output end of the second separator 32 is connected with the fractionation system.
A second output end of the second separator 32 is connected to a second input end of the second precooler 312, a second output end of the second precooler 312 is connected to a second input end of the first precooler 311, a second output end of the first precooler 311 is connected to a second input end of the heat exchanger 211, and a second output end of the heat exchanger 211 outputs dry gas.
The input end of the gas-liquid separator 11 inputs the raw material gas in a first temperature range, the gas-liquid separator 11 separates the raw material gas in the first temperature range to obtain first separated gas and liquid oil, and outputs the first separated gas to the air cooler 12 through the output end of the gas-liquid separator, and outputs the liquid oil to the primary flash steam through the other output end of the gas-liquid separator. Wherein the first temperature range is 57 ℃. The first separated gas is input to the input end of the air cooler 12, the air cooler 12 performs cooling treatment on the first separated gas, and the temperature is reduced to a fourth temperature range, and the first separated gas is output through the output end of the air cooler 12. Wherein the fourth temperature range is 40 ℃. The first separated gas is input to the first input end of the heat exchanger 211, cooled to the second temperature range, and output through the first output end thereof. Wherein the second temperature range is 25 ℃. The first separator 22 has an input for inputting a first separation gas, and separates the first separation gas in a second temperature range to obtain a second separation gas and liquid oil. And (3) separating again when the temperature is continuously reduced to below 25 ℃, and further separating out heavy hydrocarbon components to ensure that light hydrocarbons are qualified. The output end of the first separator 22 outputs the second separated gas to the first precooler 311, and the other output end outputs the liquid oil to the primary flash steam. The second separated gas passes through the first precooler 311 and is cooled to 17 ℃; through the second precooler 312, the temperature is reduced to-8.5 ℃. And adding an antifreezing agent into the precooler A and the precooler C to reduce the condensation point of water molecules in the second separation gas and prevent the water molecules from becoming solid to block the circulation of the second separation gas. The antifreeze may be ethylene glycol. The second separated gas passes through the refrigeration valve 313, is cooled to-27 ℃, and the output end of the refrigeration valve 313 outputs the second separated gas. The second separator 32 has an input for receiving a second separation gas, and performs cryogenic separation on the second separation gas to obtain liquid hydrocarbons and dry gas. The first output of the second separator 32 inputs liquid hydrocarbons. The second output of the second separator 32 outputs dry gas.
The second output of the second separator 32 outputs dry gas at-27 ℃. The dry gas is input to the second input of the second precooler 312, and after the heating treatment, the dry gas is output from the second output of the second precooler 312. The dry gas is input to the second input end of the first precooler 311, and after the heating treatment, the dry gas is output from the second output end of the first precooler 311. The second input end of the heat exchanger 211 inputs dry gas, and after the heating treatment, the second output end of the heat exchanger 211 outputs dry gas. The temperature of the dry gas is about 25 ℃, and the dry gas is collected.
The dehydration and hydrocarbon removal device provided by the embodiment reduces the temperature of the first separation gas to 25 ℃ through the heat exchanger, and then enters the first separator to separate the first separation gas, so that heavy hydrocarbon components can be further separated out to ensure that light hydrocarbon is qualified. By analysis of the hydrate formation temperature of the feed gas, the hydrate formation temperature at 10.70MPa is 18.8 ℃, and the temperature at which effective separation is performed without the addition of antifreeze should be 3 to 5 ℃ higher than the hydrate formation temperature, i.e., a minimum of 22 ℃. Therefore, the optimal separation temperature is 22-25 ℃, and the light hydrocarbon qualification can be met at the optimal separation temperature, and the addition of the antifreezing agent can be reduced to the greatest extent.
Fig. 4 is a schematic diagram of a dehydration and hydrocarbon removal apparatus provided in accordance with yet another exemplary embodiment of the present application. As shown in fig. 4, the dehydration and hydrocarbon removal device provided in this embodiment includes: the gas-liquid separator 11, the air cooler 12, the first precooler 212, the raw gas water separator 221, the second precooler 312, the refrigeration valve 313 and the low-temperature separator 321.
Wherein the primary separation unit 10 includes a gas-liquid separator 11 and an air cooler 12. The first cooler 21 comprises a precooler, which is a first precooler 212, and the first precooler 212 is composed of a feed gas precooler a and a feed gas precooler B. The first separator 22 includes a feed gas water separator 221, the second cooler 31 includes a precooler and a refrigeration valve, one precooler is a second precooler 312, the second precooler 312 is composed of a feed gas precooler C and a feed gas precooler D, and the refrigeration valve 313 is a J-T valve. The second separator 32 includes a low temperature separator 321.
The output end of the gas-liquid separator 11 is connected with the input end of the air cooler 12, the output end of the air cooler 12 is connected with the first input end of the first precooler 212, the first output end of the first precooler 212 is connected with the input end of the raw material gas water separator 221, the output end of the raw material gas water separator 221 is connected with the first input end of the second precooler 312, the first output end of the second precooler 312 is connected with the input end of the refrigeration valve 313, the output end of the refrigeration valve 313 is connected with the input end of the low-temperature separator 321, and the first output end of the low-temperature separator 321 is connected with the fractionation system.
A second output end of the low-temperature separator 321 is connected to a second input end of the second precooler 312, a second output end of the second precooler 312 is connected to a second input end of the first precooler 212, and a second output end of the first precooler 212 outputs dry gas.
The input end of the gas-liquid separator 11 is input with raw gas at 57 ℃, the gas-liquid separator 11 separates the raw gas at 57 ℃ to obtain first separated gas and liquid oil, and outputs the first separated gas to the air cooler 12 through the output end thereof, and outputs the liquid oil to the primary flash steam through the other output end thereof. The first separated gas is input to the input end of the air cooler 12, the air cooler 12 cools the first separated gas to 40 ℃, and the first separated gas is output through the output end thereof. The first separated gas is cooled by the first precooler 212 to 22 ℃ and is output to the input end of the raw gas water separator 221. The first separation gas is inputted to the input end of the raw gas water separator 221, and is separated at 22 ℃ to obtain the second separation gas and liquid oil. The output of feed gas separator 221 outputs a second separated gas to second precooler 312 and the other output outputs liquid oil to the primary flash steam. The second separated gas passes through a second precooler 312 and is cooled to-4 ℃. Ethylene glycol is added into the raw material gas precooler C to reduce the condensation point of water molecules in the second separation gas and prevent the water molecules from becoming solid to block the circulation of the second separation gas. The second separated gas passes through the refrigeration valve 313 and is cooled to-22.8 ℃, and the output end of the refrigeration valve 313 outputs the second separated gas. The second separation gas is input to the input end of the low-temperature separator 321, and the second separation gas is subjected to low-temperature separation, so as to obtain liquid hydrocarbon and dry gas. The liquid hydrocarbon is input to the first output of the cryogenic separator 321. A second output of the cryogenic separator 321 outputs dry gas.
The second output of the cryogenic separator 321 outputs dry gas at-22.8 ℃. The dry gas is input to the second input of the second precooler 312, and after the heating treatment, the dry gas is output from the second output of the second precooler 312. The dry gas is input to the second input of the first precooler 212, and after the heating treatment, the dry gas is output from the second output of the first precooler 212. The temperature of the dry gas is about 25 ℃, and the dry gas is collected.
According to the dehydration and dealkylation device provided by the embodiment, the raw material gas water separator is positioned between the raw material gas precooler B and the raw material gas precooler C, ethylene glycol is not injected into the raw material gas precooler A, the outlet temperature of the raw material gas precooler B is increased, and as the raw material gas precooler C and the raw material gas precooler D are built, the heat exchange area is certain, the inlet temperature is increased, the outlet temperature is also increased, and the throttle temperature behind the refrigeration valve is also increased. In order to reduce the heat exchange temperature of the raw material gas as much as possible, the outlet temperature of the raw material gas precooler B should be reduced as much as possible, so that the lower limit of 22 ℃ without forming hydrate is adopted.
Fig. 5 is a schematic diagram of a dehydration and hydrocarbon removal apparatus provided in accordance with yet another exemplary embodiment of the present application. As shown in fig. 5, the dehydration and hydrocarbon removal device provided in this embodiment includes: gas-liquid separator 11, air cooler 12, third separator 40, first precooler 212, three-phase separator 222, second precooler 312, refrigeration valve 313, and cryogenic separator 321.
Wherein the primary separation unit 10 includes a gas-liquid separator 11 and an air cooler 12. The first cooler 21 also comprises before it a third separator 40, which third separator 40 may be a water separator. The first cooler 21 comprises a precooler, which is a first precooler 212, and the first precooler 212 is composed of a feed gas precooler a and a feed gas precooler B. The first separator 22 includes a three-phase separator 222. The second cooler 31 comprises a precooler and a refrigeration valve, wherein one precooler is a second precooler 312, the second precooler 312 comprises a feed gas precooler C and a feed gas precooler D, and the refrigeration valve 313 is a J-T valve. The second separator 32 includes a low temperature separator 321.
The output end of the gas-liquid separator 11 is connected with the input end of the air cooler 12, the output end of the air cooler 12 is connected with the input end of a third separator, the output end of the third separator is connected with the first input end of the first precooler 212, the first output end of the first precooler 212 is connected with the input end of the three-phase separator 222, the first output end of the three-phase separator 222 is connected with the first input end of the second precooler 312, the first output end of the second precooler 312 is connected with the input end of the refrigeration valve 313, the output end of the refrigeration valve 313 is connected with the input end of the low-temperature separator 321, the first output end of the low-temperature separator 321 is connected with the fractionation system, and the second output end of the three-phase separator 222 is connected with the input end of the glycol removal regeneration device.
A second output end of the low-temperature separator 321 is connected to a second input end of the second precooler 312, a second output end of the second precooler 312 is connected to a second input end of the first precooler 212, and a second output end of the first precooler 212 outputs dry gas.
The input end of the gas-liquid separator 11 is input with raw gas at 57 ℃, the gas-liquid separator 11 separates the raw gas at 57 ℃ to obtain first separated gas and liquid oil, and outputs the first separated gas to the air cooler 12 through the output end thereof, and outputs the liquid oil to the primary flash steam through the other output end thereof. The first separated gas is input to the input end of the air cooler 12, the air cooler 12 cools the first separated gas to 40 ℃, and the first separated gas is output through the output end thereof. The third separator 40 separates the first separated gas at 40 ℃ to obtain a third separated gas and liquid oil, the third separated gas is output to the first precooler 212 through the output end of the third separator 40, and the liquid oil is output to the primary flash steam through the other output end of the third separator 40. The first separation gas is re-separated at 40 c with a low liquefaction rate of heavy hydrocarbons, resulting in a high heavy hydrocarbon content in the third separation gas, and thus, is subsequently re-separated by the three-phase separator 222. The third separation gas is cooled by a raw gas precooler A in the first precooler 212, and is cooled to 28 ℃ and is higher than 25 ℃ but does not meet the separation requirement, and the temperature is 17 ℃ to 25 ℃. The third gas is cooled by the raw gas precooler B to be cooled to 17 ℃ to meet the separation requirement, and is output to the input end of the three-phase separator 222. Ethylene glycol is injected into the raw material gas precooler A to reduce the condensation point of water molecules in the second separation gas, and prevent the water molecules from becoming solid to block the circulation of the third separation gas. The third separation gas is separated by the three-phase separator 222 to obtain a second separation gas and a condensate. The condensate contains liquid oil and ethylene glycol, and the second output end of the three-phase separator 222 outputs the condensate to the input end of the ethylene glycol removal regeneration device, and the ethylene glycol removal regeneration device recycles the ethylene glycol. The first output of the three-phase separator 222 outputs a second separated gas. The second separated gas passes through a second precooler 312 and is cooled to-8.5 ℃. Ethylene glycol is added into the raw material gas precooler C to reduce the condensation point of water molecules in the second separation gas and prevent the water molecules from becoming solid to block the circulation of the second separation gas. The second separated gas passes through the refrigeration valve 313, is cooled to-27 ℃, and the output end of the refrigeration valve 313 outputs the second separated gas. The second separation gas is input to the input end of the low-temperature separator 321, and the second separation gas is subjected to low-temperature separation, so as to obtain liquid hydrocarbon and dry gas. The liquid hydrocarbon is input to the first output of the cryogenic separator 321. A second output of the cryogenic separator 321 outputs dry gas.
The second output of the cryogenic separator 321 outputs dry gas at-27 ℃. The dry gas is input to the second input of the second precooler 312, and after the heating treatment, the dry gas is output from the second output of the second precooler 312. The dry gas is input to the second input of the first precooler 212, and after the heating treatment, the dry gas is output from the second output of the first precooler 212.
The dehydration and hydrocarbon removal device provided by the embodiment is characterized in that a third separator is arranged before a feed gas precooler A, a three-phase separator is arranged after a feed gas precooler B, and the antifreeze glycol is recycled, so that the problem of exceeding heavy hydrocarbon standard in a light hydrocarbon product is solved.
Finally, it should be noted that: the above embodiments are only for illustrating the technical solution of the present application, and not for limiting the same; although the present application has been described in detail with reference to the foregoing embodiments, it should be understood by those of ordinary skill in the art that: the technical scheme described in the foregoing embodiments can be modified or some or all of the technical features thereof can be replaced by equivalents; such modifications and substitutions do not depart from the spirit of the corresponding technical solutions from the scope of the technical solutions of the embodiments of the present application.
Claims (8)
1. A dehydration and hydrocarbon removal apparatus comprising:
the primary separation unit is used for separating the raw material gas in a first temperature range to obtain a first separated gas;
the input end of the secondary separation unit is connected with the output end of the primary separation unit and is used for separating the first separation gas in a second temperature range to obtain a second separation gas;
the input end of the third separation unit is connected with the output end of the second separation unit, and is used for separating the second separation gas at a low temperature in a third temperature range to obtain liquid hydrocarbon;
the secondary separation unit includes:
the first cooler is used for carrying out cooling treatment on the first separated gas and outputting the first separated gas through a first output end of the first cooler so as to enable the temperature of the first separated gas to be in the second temperature range;
the input end of the first separator is connected with the first output end of the first cooler, and is used for separating the first separated gas in the second temperature range and outputting the second separated gas through the output end of the first separator;
if the first cooler comprises a heat exchanger, the first temperature range is 57 ℃, the second temperature range is 25 ℃, and the third temperature range is-27 ℃.
2. The apparatus of claim 1, wherein the tertiary separation unit comprises:
the first input end of the second cooler is connected with the output end of the first separator and is used for carrying out multistage cooling treatment on the second separated gas and outputting the second separated gas through the first output end of the second cooler so as to enable the temperature of the first separated gas to be in the third temperature range;
and the input end of the second separator is connected with the first output end of the second cooler, and is used for separating the second separated gas in the third temperature range and outputting the liquid hydrocarbon through the first output end of the second separator.
3. The apparatus of claim 2, wherein a second output of the second separator is connected to a second input of the second cooler, the second output of the second cooler is connected to a second input of the first cooler, and the second separator is further configured to output dry gas through the second output and to heat treat the dry gas through the second cooler and the first cooler.
4. The apparatus of claim 2, wherein the second cooler comprises two precoolers and a refrigeration valve.
5. The apparatus of claim 2, wherein if the first cooler comprises a precooler, the second cooler comprises a precooler and a refrigeration valve; the first temperature range is 57 ℃, the second temperature range is 22 ℃, and the third temperature range is-22.8 ℃.
6. The apparatus of claim 3, wherein if the first cooler comprises a precooler, the first separator comprises a three-phase separator, the second cooler comprises a precooler and a refrigeration valve, the first cooler is preceded by a third separator for separating the first separated gas in a fourth temperature range to obtain a third separated gas; the first temperature range is 57 ℃, the second temperature range is 17 ℃, the third temperature range is-27 ℃, and the fourth temperature range is 40 ℃.
7. The apparatus of claim 1, wherein the primary separation unit comprises a gas-liquid separator;
the gas-liquid separator is used for separating the raw material gas in the first temperature range to obtain first separated gas.
8. The apparatus of claim 7, wherein the primary separation unit further comprises an air cooler;
the input end of the air cooler is connected with the output end of the gas-liquid separator, and is used for carrying out cooling treatment on the first separated gas and outputting the first separated gas through the output end of the air cooler so that the temperature of the first separated gas is within a fourth temperature range, and the fourth temperature range is 40 ℃.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202110147803.XA CN114854463B (en) | 2021-02-03 | 2021-02-03 | Dehydration and hydrocarbon removal device |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202110147803.XA CN114854463B (en) | 2021-02-03 | 2021-02-03 | Dehydration and hydrocarbon removal device |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN114854463A CN114854463A (en) | 2022-08-05 |
| CN114854463B true CN114854463B (en) | 2023-05-26 |
Family
ID=82622817
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202110147803.XA Active CN114854463B (en) | 2021-02-03 | 2021-02-03 | Dehydration and hydrocarbon removal device |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN114854463B (en) |
Citations (8)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4251249A (en) * | 1977-01-19 | 1981-02-17 | The Randall Corporation | Low temperature process for separating propane and heavier hydrocarbons from a natural gas stream |
| CN102389690A (en) * | 2011-03-23 | 2012-03-28 | 中国石油天然气股份有限公司 | Gas dehydration and dealkylation method for supersonic vortex tube |
| CN104061758A (en) * | 2014-07-01 | 2014-09-24 | 天津市振津工程设计咨询有限公司 | Device and method for removing heavy hydrocarbon in natural gas through step-by-step condensation |
| RU2543867C1 (en) * | 2014-01-09 | 2015-03-10 | Андрей Владиславович Курочкин | Method of low temperature gas separation |
| CN106152702A (en) * | 2015-04-23 | 2016-11-23 | 廊坊河忠新能源科技有限公司 | Liquid nitrogen refrigerating is utilized to reclaim the method and apparatus of lighter hydrocarbons in associated gas |
| RU2659311C1 (en) * | 2017-04-03 | 2018-06-29 | Общество с ограниченной ответственностью "Научно-исследовательский институт природных газов и газовых технологий - Газпром ВНИИГАЗ" | Method natural gas processing |
| CN111456702A (en) * | 2019-01-18 | 2020-07-28 | 中国石油天然气股份有限公司 | Oil-gas separation system and method |
| CN111849573A (en) * | 2019-04-26 | 2020-10-30 | 中国石油化工股份有限公司 | Light hydrocarbon recovery system |
-
2021
- 2021-02-03 CN CN202110147803.XA patent/CN114854463B/en active Active
Patent Citations (8)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4251249A (en) * | 1977-01-19 | 1981-02-17 | The Randall Corporation | Low temperature process for separating propane and heavier hydrocarbons from a natural gas stream |
| CN102389690A (en) * | 2011-03-23 | 2012-03-28 | 中国石油天然气股份有限公司 | Gas dehydration and dealkylation method for supersonic vortex tube |
| RU2543867C1 (en) * | 2014-01-09 | 2015-03-10 | Андрей Владиславович Курочкин | Method of low temperature gas separation |
| CN104061758A (en) * | 2014-07-01 | 2014-09-24 | 天津市振津工程设计咨询有限公司 | Device and method for removing heavy hydrocarbon in natural gas through step-by-step condensation |
| CN106152702A (en) * | 2015-04-23 | 2016-11-23 | 廊坊河忠新能源科技有限公司 | Liquid nitrogen refrigerating is utilized to reclaim the method and apparatus of lighter hydrocarbons in associated gas |
| RU2659311C1 (en) * | 2017-04-03 | 2018-06-29 | Общество с ограниченной ответственностью "Научно-исследовательский институт природных газов и газовых технологий - Газпром ВНИИГАЗ" | Method natural gas processing |
| CN111456702A (en) * | 2019-01-18 | 2020-07-28 | 中国石油天然气股份有限公司 | Oil-gas separation system and method |
| CN111849573A (en) * | 2019-04-26 | 2020-10-30 | 中国石油化工股份有限公司 | Light hydrocarbon recovery system |
Also Published As
| Publication number | Publication date |
|---|---|
| CN114854463A (en) | 2022-08-05 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| RU2662814C2 (en) | Improved hydrogen extraction | |
| WO1993013850A1 (en) | Membrane separation process for cracked gases | |
| JP3724840B2 (en) | Olefin recovery from hydrocarbon streams. | |
| US4017276A (en) | Deoxygenation of water | |
| CN108641769A (en) | A kind of recovery method of associated gas | |
| US4606816A (en) | Method and apparatus for multi-component fractionation | |
| CN114854463B (en) | Dehydration and hydrocarbon removal device | |
| DE102012003741A1 (en) | Process for the recovery of hydrocarbons from polyolefin plants and apparatus suitable therefor | |
| CN108055839B (en) | Method and apparatus for producing a mixture of carbon monoxide and hydrogen | |
| US3242682A (en) | Method for separation of hydrocarbons | |
| CN107541235B (en) | Two-stage condensation and separation method and separation system for oil gas at tower top of crude oil atmospheric distillation tower | |
| RU2470865C2 (en) | Method of preparing hydrocarbon gas and apparatus for realising said method | |
| RU2133931C1 (en) | Method of withdrawal of stable condensate from natural gas | |
| CN213085890U (en) | Multistage parallel separation processing system of heavy oil supercritical fluid extraction | |
| CN101050160A (en) | Method for separating olefin | |
| CN113566493A (en) | Cryogenic separation system for helium recovery | |
| CN114854448B (en) | Recovery device for liquefied gas in hydrogen production by reforming | |
| CN112452095A (en) | Improved tail gas rectification method | |
| KR102397789B1 (en) | Method and equipment for cryogenic separation of gas mixtures by methane scrubbing | |
| US3827245A (en) | Recovery and purification of ethylene from direct hydration ethanol vent gas streams | |
| CN210065671U (en) | Device for producing white oil by direct coal liquefaction | |
| RU2758364C1 (en) | Method for reconstruction of a low-temperature gas separation plant for the production of liquefied natural gas (options) | |
| CN112760134B (en) | Oil gas recovery method and device | |
| MX2012011362A (en) | Light gas separation from hydrocarbons for variable composition feed streams. | |
| CN108424788B (en) | Pyrolysis gas separation device and process |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |