CN116694353A - Normal top oil gas condensation cooling process and system for large atmospheric and vacuum device - Google Patents
Normal top oil gas condensation cooling process and system for large atmospheric and vacuum device Download PDFInfo
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- CN116694353A CN116694353A CN202210188800.5A CN202210188800A CN116694353A CN 116694353 A CN116694353 A CN 116694353A CN 202210188800 A CN202210188800 A CN 202210188800A CN 116694353 A CN116694353 A CN 116694353A
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- 238000009833 condensation Methods 0.000 title claims abstract description 70
- 230000005494 condensation Effects 0.000 title claims abstract description 70
- 238000001816 cooling Methods 0.000 title claims abstract description 45
- 238000000034 method Methods 0.000 title claims abstract description 28
- 239000000463 material Substances 0.000 claims abstract description 39
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 33
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 33
- 239000004215 Carbon black (E152) Substances 0.000 claims abstract description 32
- 238000005191 phase separation Methods 0.000 claims abstract description 22
- 230000002745 absorbent Effects 0.000 claims description 27
- 239000002250 absorbent Substances 0.000 claims description 27
- 238000010521 absorption reaction Methods 0.000 claims description 21
- 239000006096 absorbing agent Substances 0.000 claims description 9
- 238000005292 vacuum distillation Methods 0.000 claims description 8
- 239000007789 gas Substances 0.000 description 135
- 239000003921 oil Substances 0.000 description 91
- 239000012071 phase Substances 0.000 description 47
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 19
- 239000010865 sewage Substances 0.000 description 16
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 description 15
- 239000007788 liquid Substances 0.000 description 15
- 239000007791 liquid phase Substances 0.000 description 15
- 229910052717 sulfur Inorganic materials 0.000 description 15
- 239000011593 sulfur Substances 0.000 description 15
- 239000000446 fuel Substances 0.000 description 7
- 238000011084 recovery Methods 0.000 description 7
- 238000004523 catalytic cracking Methods 0.000 description 6
- 238000004821 distillation Methods 0.000 description 6
- 238000012545 processing Methods 0.000 description 6
- 238000010992 reflux Methods 0.000 description 6
- 238000004939 coking Methods 0.000 description 5
- 238000002485 combustion reaction Methods 0.000 description 5
- 230000003111 delayed effect Effects 0.000 description 5
- 230000000087 stabilizing effect Effects 0.000 description 4
- 238000000926 separation method Methods 0.000 description 3
- 230000005540 biological transmission Effects 0.000 description 2
- 238000006477 desulfuration reaction Methods 0.000 description 2
- 230000023556 desulfurization Effects 0.000 description 2
- 239000003915 liquefied petroleum gas Substances 0.000 description 2
- 238000012856 packing Methods 0.000 description 2
- 238000007789 sealing Methods 0.000 description 2
- 239000002699 waste material Substances 0.000 description 2
- 238000009835 boiling Methods 0.000 description 1
- 238000004891 communication Methods 0.000 description 1
- 230000008094 contradictory effect Effects 0.000 description 1
- 239000002826 coolant Substances 0.000 description 1
- 239000010779 crude oil Substances 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 239000002283 diesel fuel Substances 0.000 description 1
- 238000005194 fractionation Methods 0.000 description 1
- 239000002737 fuel gas Substances 0.000 description 1
- 238000010438 heat treatment Methods 0.000 description 1
- 238000005984 hydrogenation reaction Methods 0.000 description 1
- 230000003993 interaction Effects 0.000 description 1
- 239000003350 kerosene Substances 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 238000004064 recycling Methods 0.000 description 1
- 238000002407 reforming Methods 0.000 description 1
- 239000001993 wax Substances 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G5/00—Recovery of liquid hydrocarbon mixtures from gases, e.g. natural gas
- C10G5/06—Recovery of liquid hydrocarbon mixtures from gases, e.g. natural gas by cooling or compressing
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- Chemical & Material Sciences (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Engineering & Computer Science (AREA)
- Chemical Kinetics & Catalysis (AREA)
- General Chemical & Material Sciences (AREA)
- Organic Chemistry (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
Abstract
The application particularly relates to a condensing and cooling process and a system for oil gas on a normal top of a large atmospheric and vacuum device, which belong to the field of oil gas treatment on the normal top, and comprise the following steps: obtaining normal top oil gas with set temperature and first pressure; performing first condensation treatment on the normally-topped oil gas to obtain a first condensation material; carrying out first phase separation treatment on the first condensed material to obtain first naphtha and first oil gas; performing second condensation treatment on the first oil gas to obtain a second condensation material; carrying out second phase separation treatment on the second condensed material to obtain second naphtha and second oil gas; and (3) carrying out light hydrocarbon removal treatment on the second oil gas by using the first naphtha to obtain the normally-topped noncondensable gas. After the normal top oil gas is subjected to first condensation treatment and first phase separation treatment, stable naphtha can be directly obtained, and the output of unstable naphtha is reduced; after the second oil gas is subjected to light hydrocarbon removal by the first naphtha, the C3 and above components are greatly reduced, and the output of normally-topped noncondensable gas is reduced.
Description
Technical Field
The application relates to the field of normal-top oil gas treatment, in particular to a condensation cooling process and system for normal-top oil gas of a large normal-pressure reducing device.
Background
The atmospheric and vacuum distillation process is a physical fractionation process for obtaining required straight run naphtha, kerosene, diesel oil, wax oil and vacuum residuum by heating, and then performing atmospheric distillation and vacuum distillation according to the difference of boiling points or vapor pressures of the components contained in crude oil.
In recent years, the number of large-scale atmospheric and vacuum devices in China is rapidly increased, and the output of normally-on oil gas is obviously increased along with the increase of the processing capacity of the devices. When the conventional large-scale normal top oil gas condensation cooling process is used for treating normal top oil gas, a large amount of unstable naphtha which cannot be directly utilized is generated, so that the load of a downstream device for treating the large amount of unstable naphtha is increased. In addition, in the conventional produced normal top noncondensable gas, the content of the C3 and above light hydrocarbon components is higher, if the normal top noncondensable gas is directly used as fuel for combustion, larger waste of the C3 and above light hydrocarbon resources can be caused, if the normal top noncondensable gas is sent to a catalytic cracking device or a delayed coking device, after re-pressurization, recycling of the C3 and above light hydrocarbon and desulfurization, the normal top noncondensable gas is used as fuel for combustion, the load of each supercharging equipment can be increased, and the size of an external transmission pipeline of normal top oil gas is also increased.
Disclosure of Invention
The application provides a process and a system for condensing and cooling oil gas on the top of a large atmospheric and vacuum distillation device, which are used for solving the technical problem that a large amount of unstable naphtha in the large atmospheric and vacuum distillation device cannot be treated in the prior art.
In one aspect, the embodiment of the application provides a condensation cooling process for oil gas on a top of a large atmospheric and vacuum device, which comprises the following steps:
a process for condensing and cooling oil gas on a large atmospheric and vacuum device, comprising:
obtaining normal top oil gas with set temperature and first pressure;
performing first condensation treatment on the normally-topped oil gas at a first condensation temperature and a first pressure to obtain a first condensation material;
carrying out first phase separation treatment on the first condensed material to obtain first naphtha and first oil gas;
wherein the set temperature is 140-160 ℃, and the first pressure is 0.08-0.15 MPa; the first condensation temperature is 100-120 ℃.
Optionally, the process further comprises:
performing second condensation treatment on the first oil gas at a second condensation temperature to obtain a second condensation material;
carrying out second phase separation treatment on the second condensed material under a second pressure to obtain second naphtha and second oil gas;
and carrying out light hydrocarbon removal treatment on the second oil gas by using the first naphtha to obtain the normally-topped noncondensable gas.
Optionally, the second condensation temperature is less than or equal to 40 ℃.
Optionally, the second pressure is 0.030MPa to 0.045MPa.
Optionally, the step of performing light hydrocarbon removal treatment on the second oil gas by using the first naphtha to obtain a normally-top noncondensable gas specifically includes:
cooling the first naphtha to obtain a product naphtha and an absorbent naphtha;
and (3) carrying out light hydrocarbon removal treatment on the second oil gas by using the absorbent naphtha to obtain the normally-topped noncondensable gas.
Optionally, the removing light hydrocarbon treatment of the second oil gas with the absorbent naphtha to obtain a normally-top noncondensable gas specifically includes:
and carrying out light hydrocarbon removal treatment on the second oil gas by countercurrent absorption in an absorption tower by using the absorbent naphtha to obtain normally-overhead noncondensable gas, wherein the Quan Da pressure drop of the absorption tower is controlled to be less than or equal to 5kPa.
Optionally, the cooling treatment is performed on the first naphtha to obtain a product naphtha and an absorbent naphtha, which specifically includes:
carrying out first cooling treatment on the first naphtha at a first cooling temperature to obtain a product naphtha and a heat absorber naphtha;
and carrying out second cooling treatment on the hot absorbent naphtha at a second cooling temperature to obtain absorbent naphtha.
Optionally, the first cooling temperature is less than or equal to 40 ℃.
Optionally, the second cooling temperature is less than or equal to 25 ℃.
On the other hand, the embodiment of the application also provides a large atmospheric-vacuum device atmospheric-top oil gas condensation cooling system, which comprises:
the first-stage condensation system is used for carrying out first condensation treatment on the normally-top oil gas at a first condensation temperature and a first pressure to obtain a first condensation material;
the first-stage naphtha container is used for carrying out first phase separation treatment on the first-stage condensate material to obtain first naphtha and first oil gas, and the first-stage naphtha container is communicated with the first-stage condensation system.
Compared with the prior art, the technical scheme provided by the embodiment of the application has the following advantages:
the normal-top oil gas is distilled out from the top of the normal-pressure tower, enters a first naphtha container after first condensation treatment, and is controlled to be 140-160 ℃ and 0.08-0.15 MPa by controlling the set temperature of the normal-top oil gas; the first condensing temperature of the first condensing treatment is controlled at 100-120 ℃, heavy components in normal top oil gas are condensed into liquid state at the first condensing temperature, the liquid state and gaseous components are mixed into a first condensed material to enter a first naphtha container, and meanwhile, gas-liquid phase separation of the first condensed material in the first naphtha container is carried out to obtain first naphtha and first oil gas respectively, so that stable first naphtha can be directly extracted from the normal top oil gas, and unstable naphtha is reduced.
And (3) carrying out second condensation treatment on the first oil gas at a second condensation temperature, wherein the second condensation temperature is controlled to be less than or equal to 40 ℃, and the second pressure is controlled to be 0.030-0.045 MPa, so that heavy components in the normally-on oil gas are further condensed into liquid state, are mixed with gaseous components to form a second condensation material, enter a second naphtha container, and meanwhile, the gas-liquid phase separation of the second condensation material in the second naphtha container is carried out to obtain second naphtha and second oil gas respectively.
And (3) carrying out light hydrocarbon removal treatment on the second oil gas by using the first naphtha to obtain the normally-topped noncondensable gas. After the second oil gas is subjected to light hydrocarbon removal by the first naphtha, the C3 and above components are greatly reduced, and the output of normally-overhead non-condensing gas is further reduced.
The foregoing description is only an overview of the present application, and is intended to be implemented in accordance with the teachings of the present application in order that the same may be more clearly understood and to make the same and other objects, features and advantages of the present application more readily apparent.
Drawings
The accompanying drawings, which are incorporated in and constitute a part of this specification, illustrate embodiments consistent with the application and together with the description, serve to explain the principles of the application.
In order to more clearly illustrate the embodiments of the application or the technical solutions of the prior art, the drawings which are used in the description of the embodiments or the prior art will be briefly described, and it will be obvious to a person skilled in the art that other drawings can be obtained from these drawings without inventive effort.
FIG. 1 is a schematic diagram of a condensing and cooling system for oil gas on top of a large atmospheric and vacuum device according to an embodiment of the present application.
Reference numerals:
10-first-stage condensing system, 11-first-stage condenser, 12-first-stage condensing temperature control device, 20-first-stage naphtha container, 21-first-stage sulfur-containing sewage pump, 22-first-stage naphtha pump, 30-second-stage condenser, 40-second-stage naphtha container, 41-second-stage sulfur-containing sewage pump, 42-second-stage naphtha pump, 50-absorption tower, 51-top head, 52-bottom head, 60-first-stage cooler, 70-second-stage cooler, 80-first-stage cascade liquid level control loop, 90-first-stage interface control loop, 100-second-stage cascade liquid level control loop, 110-second-stage interface control loop, 120-pressure control loop and 130-flow control loop.
Detailed Description
For the purpose of making the objects, technical solutions and advantages of the embodiments of the present application more apparent, the technical solutions of the embodiments of the present application will be clearly and completely described below with reference to the accompanying drawings in the embodiments of the present application, and it is apparent that the described embodiments are some embodiments of the present application, but not all embodiments of the present application. All other embodiments, which can be made by those skilled in the art based on the embodiments of the application without making any inventive effort, are intended to be within the scope of the application.
It should be noted that all directional indicators (such as up, down, left, right, front, and rear … …) in the embodiments of the present application are merely used to explain the relative positional relationship, movement, etc. between the components in a particular posture (as shown in the drawings), and if the particular posture is changed, the directional indicator is changed accordingly.
In the present application, unless specifically stated and limited otherwise, the terms "connected," "affixed," and the like are to be construed broadly, and for example, "affixed" may be a fixed connection, a removable connection, or an integral body; can be mechanically or electrically connected; either directly or indirectly, through intermediaries, or both, may be in communication with each other or in interaction with each other, unless expressly defined otherwise. The specific meaning of the above terms in the present application can be understood by those of ordinary skill in the art according to the specific circumstances.
In addition, if there is a description of "first", "second", etc. in the embodiments of the present application, the description of "first", "second", etc. is for descriptive purposes only and is not to be construed as indicating or implying a relative importance or implicitly indicating the number of technical features indicated. Thus, a feature defining "a first" or "a second" may explicitly or implicitly include at least one such feature. In addition, the meaning of "and/or" as it appears throughout includes three parallel schemes, for example "A and/or B", including the A scheme, or the B scheme, or the scheme where A and B are satisfied simultaneously. In addition, the technical solutions of the embodiments may be combined with each other, but it is necessary to base that the technical solutions can be realized by those skilled in the art, and when the technical solutions are contradictory or cannot be realized, the combination of the technical solutions should be considered to be absent and not within the scope of protection claimed in the present application.
In the atmospheric and vacuum distillation process, for the oil gas at the top of the atmospheric distillation tower (hereinafter referred to as "atmospheric top oil gas") produced at the top of the atmospheric distillation tower, unstable naphtha, non-condensable gas at the top of the atmospheric distillation tower (hereinafter referred to as "atmospheric top non-condensable gas") and sulfur-containing sewage at the top of the atmospheric distillation tower (hereinafter referred to as "atmospheric top sulfur-containing sewage") are produced after primary or secondary condensation cooling and oil-water separation in a common processing flow. Wherein the unstable naphtha is generally fed into a light hydrocarbon recovery unit (or device) to produce a stabilized naphtha (C4 and below components content < 0.5 wt%), liquefied gas and noncondensable gas. The normal-top noncondensable gas is usually pressurized to 0.4 MPa-0.5 MPa (A) together with the reduced-top noncondensable gas by a compressor (such as a screw compressor) or a liquid ring pump, and then desulfurized in the device and then used as fuel gas, and can also be sent to a catalytic cracking device or a delayed coking device for combustion as fuel after re-pressurization, recovery of light hydrocarbons of C3 and above and desulfurization. The normal top sulfur-containing sewage is sent to a whole factory sewage stripping device.
In the existing normal top oil gas treatment process, the following problems exist:
firstly, the produced naphtha is unstable naphtha, the flash point of the unstable naphtha is too low to be safely stored because of higher light hydrocarbon content, and the invalid processing load of the device is increased in a downstream device (such as reforming and the like), so that the unstable naphtha can be qualified and stable naphtha products after being continuously sent into a light hydrocarbon recovery unit (or device) for processing, but the processing load of the original light hydrocarbon recovery unit (or device) is gradually increased;
in the produced normal top noncondensable gas, the content of the light hydrocarbon components with the concentration of C3 and above is higher, if the normal top noncondensable gas is directly pressurized and desulfurized in the device and then is used as fuel for combustion, the light hydrocarbon resources with the concentration of C3 and above are greatly wasted, if the normal top noncondensable gas is pressurized in the device and is sent to a catalytic cracking device or a delayed coking device, after the normal top noncondensable gas is pressurized again, the light hydrocarbon with the concentration of C3 and above is recycled and desulfurized, the normal top noncondensable gas is used as fuel for combustion, the load of each pressurizing device is increased, and the size of an external conveying pipeline of normal top oil gas is also increased.
Patent CN205420292U refers to a method for utilizing normal top oil gas, namely, a compressor is utilized to directly convey the normal top oil gas to a catalytic cracking device in a pressurizing way, and C3 and above components in the normal top oil gas are effectively recovered;
patent CN107189808A mentions a normal pressure tower top oil gas treatment method, namely, firstly, normal top oil gas is condensed and cooled at one stage and then enters a tower top reflux tank to be separated into a gas phase and a liquid phase; the liquid phase is divided into two paths, one path is used as reflux and enters the top of the atmospheric tower, the other path is used as a sending device, the gas phase enters a compressor, compressed gas is delivered to the inlet of a rich gas compressor of a catalytic cracking device, a delayed coking device and the like, compressed gas enters an absorption stabilizing system again, and products such as dry gas, liquefied petroleum gas and the like are separated in the absorption stabilizing system.
The normal top oil gas treatment process mentioned in the above patent cannot treat a large amount of unstable naphtha in a large normal-pressure distillation device, so that the loads of a downstream light hydrocarbon recovery unit (or device) and normal top oil gas supercharging equipment still maintain high level, and the size of an external transmission pipeline of normal top oil gas is still larger.
As shown in fig. 1, according to an exemplary embodiment of the present application, there is provided a process for condensing and cooling oil gas on top of a large atmospheric and vacuum device, the process comprising:
s1, obtaining normal-top oil gas with a set temperature and a first pressure, wherein the set temperature is 140-160 ℃, the first pressure is 0.08-0.15 MPa, and in the embodiment of the application, the first pressure is gauge pressure;
s2, performing first condensation treatment on the normally-topped oil gas at a first condensation temperature and a first pressure to obtain a first condensation material;
the first condensation temperature is 100-120 ℃, at which heavy components in the normally-topped oil gas are condensed into a liquid phase, and light components are gas phases, and the heavy components and the gas phases are taken as a first condensation material to enter a step S3;
s3, carrying out first phase separation treatment on the first condensed material under a first pressure to obtain first naphtha, first oil gas and first-stage sulfur-containing sewage, wherein under the pressure, the first phase separation is carried out to obtain gas phase, water phase and oil phase three-phase separation, in the step S2, the gas phase and the liquid phase are subjected to pre-separation, and in the step, the oil phase and the water phase are mainly separated;
s4, performing second condensation treatment on the first oil gas at a second condensation temperature to obtain a second condensation material, wherein at the second condensation temperature, heavier components in the first oil gas are condensed into a liquid phase, lighter components are gas phases, and the second condensation material is taken as the second condensation material to enter the step S5;
wherein the second condensation temperature is less than or equal to 40 ℃;
s5, carrying out second phase separation treatment on the second condensed material under a second pressure to obtain second naphtha, second oil gas and second-stage sulfur-containing sewage, wherein the second phase is separated into gas phase, water phase and oil phase three-phase separation under the pressure, the gas phase and the liquid phase are subjected to pre-separation in the step S4, and the oil phase and the water phase are mainly separated in the step;
wherein the second pressure is 0.030MPa to 0.045MPa, and the second pressure is gauge pressure;
s6, carrying out light hydrocarbon removal treatment on the second oil gas by using the first naphtha to obtain a normally-topped noncondensable gas;
as an implementation manner of the embodiment of the present application, the S6 specifically includes:
s6.1, performing first cooling treatment on the first naphtha at a first cooling temperature to obtain product naphtha and heat absorber naphtha;
s6.2, performing second cooling treatment on the thermal absorbent naphtha at a second cooling temperature to obtain absorbent naphtha;
s6.3, carrying out light hydrocarbon removal treatment on the second oil gas by using the absorbent naphtha in a countercurrent absorption mode in an absorption tower to obtain the normally-top noncondensable gas.
Wherein the first cooling temperature is less than or equal to 40 ℃, the second cooling temperature is less than or equal to 25 ℃, and the Quan Da pressure drop of the absorption tower is controlled to be less than or equal to 5kPa.
In the embodiment of the application, the first condensing temperature and the first pressure can be adjusted according to the specific component condition of the normally-on oil gas so as to achieve the specific component target of the naphtha product.
The normal-top oil gas is distilled out from the top of the normal-pressure tower, enters a first naphtha container after first condensation treatment, and is controlled to be 140-160 ℃ by controlling the set temperature of the normal-top oil gas, and the first pressure is 0.08-0.15 MPa (G); the first condensing temperature of the first condensing treatment is controlled at 100-120 ℃, heavy components in normal-top oil gas are condensed into liquid state at the first condensing temperature, the liquid state and gaseous components are mixed into a first condensed material, the first condensed material enters a first naphtha container, and meanwhile, the gas-liquid phase of the first condensed material in the first naphtha container is separated into first naphtha and first oil gas respectively by controlling the first pressure in the first naphtha container, so that stable naphtha can be directly extracted from the normal-top oil gas, namely, the content of C4 and the components below is less than 0.5 weight percent, and unstable naphtha is further reduced.
And meanwhile, part of the first naphtha is separated out to serve as an absorbent, and part of C3 and above light hydrocarbon components in the second oil gas are absorbed in a countercurrent manner, so that the C3 and above light hydrocarbon components are effectively recovered.
According to another exemplary embodiment of the present application, there is provided a large atmospheric and vacuum device overhead oil gas condensation cooling system, including:
the primary condensation system 10 is configured to perform a first condensation treatment on the normal top oil gas at a first condensation temperature and a first pressure to obtain a first condensation material, in the embodiment of the present application, the primary condensation system 10 includes a primary condenser 11 and a primary condensation temperature control device 12, a feed inlet of the primary condenser 11 is connected to a top of the atmospheric tower, a discharge outlet is connected to a feed inlet of the primary naphtha container 20, a temperature sensor of the primary condensation temperature control device 12 is disposed at a discharge outlet of the primary condenser 11, and a controller is disposed at a cold medium side of the primary condenser 11 to control the first condensation temperature of the normal top oil gas by controlling a flow rate of the cold medium;
the first-stage naphtha container 20 is used for carrying out first phase separation treatment on the first-stage condensed material under a first pressure to obtain first naphtha and first oil gas, the first-stage naphtha container 20 is communicated with the first-stage condenser 11, and the first-stage naphtha container 20 is provided with a gas phase outlet, an oil phase outlet and a water phase outlet which are respectively arranged at the top, the bottom and the water drum part of the first-stage naphtha container 20; in the embodiment of the application, the first phase separation treatment is to perform three-phase separation after standing on the first condensate material to obtain an oil phase, a water phase and a gas phase, wherein the oil phase is first naphtha, namely stable naphtha with the content of C4 and following components less than 0.5wt%, the water phase is sulfur-containing sewage, the water phase is pressurized by a first-stage sulfur-containing sewage pump 21 through a water phase outlet and then is cooled and sent to a downstream sulfur-containing sewage stripping device, and the gas phase is first oil gas.
As an implementation manner of the embodiment of the present application, the system further includes:
the second condenser 30 is configured to perform a second condensation treatment on the first oil gas at a second condensation temperature to obtain a second condensation material, in the embodiment of the present application, a feed inlet of the second condenser 30 is connected to a gas phase outlet of the first naphtha container 20, a discharge outlet is connected to a feed inlet of the second naphtha container 40, and the second condensation temperature of the first oil gas is controlled by controlling a flow of a cooling medium;
a second-stage naphtha container 40 for performing a second phase separation treatment on the second condensed material under a second pressure to obtain a second naphtha and a second oil gas, wherein the second-stage naphtha container 40 is provided with a reflux material port, a gas phase outlet, an oil phase outlet and a water phase outlet, which are respectively arranged at the top, the bottom and the water drum part of the first-stage naphtha container 20; in the embodiment of the application, the second phase separation treatment is to perform three-phase separation after standing on the second condensate material to obtain an oil phase, a water phase and a gas phase, wherein the oil phase is second naphtha, namely unstable naphtha with the content of C4 and the following components more than 0.5 weight percent, the water phase is sulfur-containing sewage, the second condensate material is pressurized by a second-stage sulfur-containing sewage pump 41 and then cooled and sent to a downstream sulfur-containing sewage stripping device, and the gas phase is second oil gas;
the absorption tower 50 is used for carrying out light hydrocarbon removal treatment on the second oil gas to obtain normally-top noncondensable gas, and the absorption tower 50 is provided with a liquid phase inlet, a liquid phase outlet, a gas phase inlet and a gas phase outlet which are respectively arranged at the top of the tower, a tower bottom sealing head 52, a tower bottom and a tower top sealing head 51. In the embodiment of the application, the absorption tower 50 is a packed tower, random or structured packing is adopted as the packing, the theoretical plate number is 2-6, and the pressure drop of the whole tower is less than or equal to 5kPa.
The first naphtha from the primary naphtha vessel 20 is pressurized by the primary naphtha pump 22 and then divided into three parts: the first part is used as the reflux of the normal pressure tower top, and is injected back to the normal pressure tower to provide the cold reflux of the tower top for the normal pressure tower; the second part is cooled to less than or equal to 40 ℃ by a primary cooler 60 and then directly enters a downstream tank area or a naphtha hydrogenation device as a product naphtha; the first naphtha of the third part is hot absorbent naphtha, and after being cooled to less than or equal to 25 ℃ by a secondary cooler 70, the absorbent naphtha is used as absorbent naphtha, the flow of the absorbent naphtha is controlled to be 8000 kg/h-15000 kg/h, and the absorbent naphtha enters from a liquid phase inlet of an absorption tower 50 to absorb C3 and above components in the second oil gas.
The gas phase from the second-stage naphtha container 40 enters from the gas phase inlet of the absorber 50 and is in countercurrent contact with absorbent naphtha from bottom to top, after the partial C3 and above light hydrocarbon components in the second oil gas are further removed through the absorption process, normal top noncondensable gas (the content of the C3 and above components is less than 30 mol%) is obtained at the top of the absorber 50, the normal top noncondensable gas can be directly used as fuel after being desulfurized in the device, and can also be pressurized and sent to the rich gas compressor inlet of devices such as catalytic cracking, delayed coking and the like, and after being pressurized again, the rich gas enters an absorption stabilizing system, and products such as dry gas, liquefied petroleum gas and the like are separated in the absorption stabilizing system. The absorbent naphtha after the absorption flows out from the liquid phase outlet of the absorption tower 50, returns to the secondary naphtha container 40 through the reflux material port of the secondary naphtha container 40, and is pumped out from the oil phase outlet through the secondary naphtha pump 42 and is sent to the downstream light hydrocarbon recovery unit or device together with the second naphtha separated from the secondary naphtha container 40.
As an embodiment of the present application, a primary cascade liquid level control circuit 80 is disposed between the liquid level of the primary naphtha container 20 and the outlet of the primary cooler 60, for controlling the liquid level of the liquid phase in the primary naphtha container 20.
As an implementation manner of the embodiment of the application, a primary interface control loop 90 is arranged between the oil-water interface of the primary naphtha container 20 and the outlet of the primary sulfur-containing sewage pump 21, and is used for controlling the liquid level of the water phase in the primary naphtha container 20.
As an implementation manner of the embodiment of the present application, a secondary cascade level control loop 100 is disposed between the liquid level of the secondary naphtha container 40 and the outlet of the secondary naphtha pump 42, for controlling the liquid level of the liquid phase in the secondary naphtha container 40.
As an implementation manner of the embodiment of the present application, a second-stage interface control loop 110 is disposed between the oil-water interface of the second-stage naphtha container 40 and the outlet of the second-stage sulfur-containing sewage pump 41, and is used for controlling the liquid level of the water phase in the second-stage naphtha container 40.
As an implementation manner of the embodiment of the present application, a pressure control loop 120 is disposed between the top of the primary naphtha container 20, the top of the secondary naphtha container 40 and the gas phase outlet pipeline of the absorber 50, so as to control the pressures of the top of the primary naphtha container 20, the top of the secondary naphtha container 40 and the absorber 50, and the flow rate of the normally-top noncondensable gas.
As an embodiment of the present application, a flow control circuit 130 is provided between the secondary cooler 70 and the absorber 50 for controlling the flow rate of the absorbent naphtha.
So set up, through direct production partly stable naphtha, reduce unstable naphtha output, reached the purpose that reduces low reaches light ends recovery unit (or device) load, in addition through setting up absorber 50, with the first naphtha that first naphtha container was produced certainly as the absorbent, retrieve some C3 and above components in the second oil gas, when having reduced the direct fuel of second oil gas, the waste of light ends resource has also reduced the processing load and the normal top oil gas export pipeline size of normal top oil gas supercharging equipment.
The foregoing is only a specific embodiment of the application to enable those skilled in the art to understand or practice the application. Various modifications to these embodiments will be readily apparent to those skilled in the art, and the generic principles defined herein may be applied to other embodiments without departing from the spirit or scope of the application. Thus, the present application is not intended to be limited to the embodiments shown herein but is to be accorded the widest scope consistent with the principles and novel features disclosed herein.
Claims (10)
1. The process for condensing and cooling the oil gas on the top of the large atmospheric and vacuum device is characterized by comprising the following steps of:
obtaining normal top oil gas with set temperature and first pressure;
performing first condensation treatment on the normally-topped oil gas at a first condensation temperature and a first pressure to obtain a first condensation material;
carrying out first phase separation treatment on the first condensed material to obtain first naphtha and first oil gas;
wherein the set temperature is 140-160 ℃, and the first pressure is 0.08-0.15 MPa; the first condensation temperature is 100-120 ℃.
2. The process for condensing and cooling off oil gas on top of a large atmospheric and vacuum device according to claim 1, further comprising:
performing second condensation treatment on the first oil gas at a second condensation temperature to obtain a second condensation material;
carrying out second phase separation treatment on the second condensed material under a second pressure to obtain second naphtha and second oil gas;
and carrying out light hydrocarbon removal treatment on the second oil gas by using the first naphtha to obtain the normally-topped noncondensable gas.
3. The process for condensing and cooling oil gas on top of a large atmospheric and vacuum device according to claim 2, wherein the second condensing temperature is less than or equal to 40 ℃.
4. The process for condensing and cooling oil gas on top of a large atmospheric and vacuum device according to claim 2, wherein the second pressure is 0.030MPa to 0.045MPa.
5. The condensing and cooling process of the atmospheric and overhead oil gas of the large atmospheric and vacuum device according to claim 2, wherein the light hydrocarbon removal treatment is performed on the second oil gas by using the first naphtha to obtain the atmospheric and overhead noncondensable gas, specifically comprising:
cooling the first naphtha to obtain a product naphtha and an absorbent naphtha;
and (3) carrying out light hydrocarbon removal treatment on the second oil gas by using the absorbent naphtha to obtain the normally-topped noncondensable gas.
6. The condensing and cooling process for atmospheric and overhead oil gas of a large atmospheric and vacuum distillation apparatus according to claim 5 wherein said subjecting said second oil gas to said light hydrocarbon removal treatment with said absorbent naphtha to obtain an atmospheric and overhead noncondensable gas comprises:
and carrying out light hydrocarbon removal treatment on the second oil gas by countercurrent absorption in an absorption tower by using the absorbent naphtha to obtain normally-overhead noncondensable gas, wherein the Quan Da pressure drop of the absorption tower is controlled to be less than or equal to 5kPa.
7. The process for condensing and cooling normal top oil gas of a large atmospheric and vacuum device according to claim 5, wherein said cooling said first naphtha to obtain a product naphtha and an absorbent naphtha comprises:
carrying out first cooling treatment on the first naphtha at a first cooling temperature to obtain a product naphtha and a heat absorber naphtha;
and carrying out second cooling treatment on the hot absorbent naphtha at a second cooling temperature to obtain absorbent naphtha.
8. The process for condensing and cooling oil gas on top of a large atmospheric and vacuum distillation apparatus according to claim 7 wherein said first cooling temperature is less than or equal to 40 ℃.
9. The process for condensing and cooling oil gas on top of a large atmospheric and vacuum distillation apparatus according to claim 7 wherein said second cooling temperature is no greater than 25 ℃.
10. A large atmospheric-vacuum device atmospheric-top oil-gas condensation cooling system, comprising:
the first-stage condensation system (10) is used for carrying out first condensation treatment on the normally-top oil gas at a first condensation temperature and a first pressure to obtain a first condensation material;
and the first-stage naphtha container (20) is used for carrying out first phase separation treatment on the first-stage condensed material to obtain first naphtha and first oil gas, and the first-stage naphtha container (20) is communicated with the first-stage condensation system (10).
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202210188800.5A CN116694353A (en) | 2022-02-28 | 2022-02-28 | Normal top oil gas condensation cooling process and system for large atmospheric and vacuum device |
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| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202210188800.5A CN116694353A (en) | 2022-02-28 | 2022-02-28 | Normal top oil gas condensation cooling process and system for large atmospheric and vacuum device |
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| CN116694353A true CN116694353A (en) | 2023-09-05 |
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| CN202210188800.5A Pending CN116694353A (en) | 2022-02-28 | 2022-02-28 | Normal top oil gas condensation cooling process and system for large atmospheric and vacuum device |
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| Country | Link |
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