CN113122302B - Condensation method oil gas recovery method and device - Google Patents
Condensation method oil gas recovery method and device Download PDFInfo
- Publication number
- CN113122302B CN113122302B CN201911418148.6A CN201911418148A CN113122302B CN 113122302 B CN113122302 B CN 113122302B CN 201911418148 A CN201911418148 A CN 201911418148A CN 113122302 B CN113122302 B CN 113122302B
- Authority
- CN
- China
- Prior art keywords
- gas
- oil
- condenser
- deep
- pass
- 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
- 238000000034 method Methods 0.000 title claims abstract description 50
- 238000009833 condensation Methods 0.000 title claims abstract description 39
- 230000005494 condensation Effects 0.000 title claims abstract description 39
- 238000011084 recovery Methods 0.000 title claims abstract description 35
- 239000003507 refrigerant Substances 0.000 claims abstract description 55
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 27
- 238000010257 thawing Methods 0.000 claims abstract description 23
- 239000007788 liquid Substances 0.000 claims abstract description 22
- 238000000926 separation method Methods 0.000 claims abstract description 13
- 238000001816 cooling Methods 0.000 claims abstract description 12
- 239000002826 coolant Substances 0.000 claims abstract 3
- 230000018044 dehydration Effects 0.000 claims description 2
- 238000006297 dehydration reaction Methods 0.000 claims description 2
- 230000008901 benefit Effects 0.000 abstract description 4
- 239000007789 gas Substances 0.000 description 109
- 239000003921 oil Substances 0.000 description 98
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 9
- 238000001179 sorption measurement Methods 0.000 description 8
- 238000005265 energy consumption Methods 0.000 description 7
- 229910052799 carbon Inorganic materials 0.000 description 5
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 4
- 239000003463 adsorbent Substances 0.000 description 4
- 238000002425 crystallisation Methods 0.000 description 3
- 230000008025 crystallization Effects 0.000 description 3
- 238000003795 desorption Methods 0.000 description 3
- 238000005516 engineering process Methods 0.000 description 3
- 238000005057 refrigeration Methods 0.000 description 3
- 239000012855 volatile organic compound Substances 0.000 description 3
- RTZKZFJDLAIYFH-UHFFFAOYSA-N Diethyl ether Chemical compound CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 description 2
- 238000004134 energy conservation Methods 0.000 description 2
- 238000004880 explosion Methods 0.000 description 2
- 239000000446 fuel Substances 0.000 description 2
- 229910052757 nitrogen Inorganic materials 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 description 1
- 238000010521 absorption reaction Methods 0.000 description 1
- 150000001299 aldehydes Chemical class 0.000 description 1
- 150000004945 aromatic hydrocarbons Chemical class 0.000 description 1
- 239000010779 crude oil Substances 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 238000003912 environmental pollution Methods 0.000 description 1
- 238000001704 evaporation Methods 0.000 description 1
- 230000008020 evaporation Effects 0.000 description 1
- 239000002360 explosive Substances 0.000 description 1
- 239000003350 kerosene Substances 0.000 description 1
- 150000002576 ketones Chemical class 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000013021 overheating Methods 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 239000000341 volatile oil Substances 0.000 description 1
Images
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
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
- Y02P70/00—Climate change mitigation technologies in the production process for final industrial or consumer products
- Y02P70/10—Greenhouse gas [GHG] capture, material saving, heat recovery or other energy efficient measures, e.g. motor control, characterised by manufacturing processes, e.g. for rolling metal or metal working
Landscapes
- 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)
- Vaporization, Distillation, Condensation, Sublimation, And Cold Traps (AREA)
Abstract
The invention discloses a method for recovering oil gas by a condensation method. The method comprises the following steps: (1) Providing two deep coolers A/C, providing a pre-condenser B, an oil storage tank and a water storage tank; (2) Oil gas to be treated firstly enters a pipe pass of a chiller A, flows through the chiller A and then enters a pipe pass of a pre-condenser B; (3) Gas-liquid separation is carried out on the precooled oil gas, the separated gas enters a pipe pass of a deep cooler C and is cooled by a cryogenic coolant, and oil-gas condensation is realized; (4) Condensed oil gas enters a separation device to separate out condensate liquid, and purified gas enters a next processing unit to be processed; (5) When the deep cooler C needs defrosting, switching oil gas to be treated to enter a tube pass of the deep cooler C, and switching a shell pass of the deep cooler C from deep cooling secondary refrigerant to shallow cooling secondary refrigerant; (6) And defrosting the condenser C to obtain liquid, feeding the liquid into a water storage tank, and allowing the pre-condensed gas to sequentially flow through the pre-condenser B and the condenser A to realize oil gas recovery. The method of the invention has no ice blockage problem of the system, and has the advantages of stability, reliability, safety, energy saving and the like.
Description
Technical Field
The invention relates to the technical field of environmental protection and energy conservation, and relates to an oil gas recovery processing device, in particular to a recovery processing device for volatile oil gas of oil products or chemicals such as gasoline, naphtha, crude oil, aviation kerosene, aromatic hydrocarbon, alcohol, aldehyde, ketone, ether and the like.
Background
During storage and transportation of oil and chemicals, large amounts of oil and gas or Volatile Organic Compounds (VOCs) are lost. According to statistics, the oil loss caused by the loss of light oil products accounts for about 0.5 percent of the light oil products each year, on one hand, a large amount of oil gas or volatile organic compounds are wasted, the economic benefit of enterprises is reduced, and on the other hand, serious environmental pollution is caused. In addition, as the oil gas and the air are easy to form an explosive mixture (the lower explosion limit is generally 1% -6%), the oil gas dissipation can cause the concentration of the oil gas around corresponding facilities to easily reach the explosion limit, and the oil gas gathered on the ground brings great potential safety hazards to enterprises and consumers, thereby endangering the safety production of the enterprises and directly influencing the health of operators and surrounding environment personnel. Therefore, it is necessary to recover the dissipated oil gas.
The traditional oil gas recovery treatment mode has three kinds: firstly, the fuel is directly used as fuel; oil gas is returned to the oil tank gas-liquid balance system, so that the oil gas partial pressure is increased, and the evaporation loss of oil products is reduced; thirdly, recovery devices and technologies are adopted, such as a condensation method, an absorption method, an adsorption method, a combined process thereof and the like.
WO9604978 adopts active carbon as adsorbent, uses two-tower alternate regeneration-adsorption process, vacuum pump pressure swing desorption, and desorbed gas is condensed and recovered by condenser. When the active carbon adsorbs oil gas components, the adsorption heat release enables the temperature of an active carbon bed layer to be greatly increased, and particularly when the oil gas concentration is high, the active carbon bed layer is easy to generate a local overheating phenomenon, so that the service life of the adsorbent is shortened, and potential safety hazards exist in the operation process. In addition, when the oil gas contains more high-boiling-point organic matters, the organic matters are easily adsorbed by activated carbon, but are difficult to desorb through vacuum pumping, which can remarkably reduce the service life of the adsorbent.
CN1494454A discloses a device for recovering organic matters by an activated carbon adsorption method, after adsorption is stopped, organic components are desorbed and adsorbed by steam, and then the organic components enter a condenser for condensation to recover condensed oil and condensed water; the steam thermal desorption efficiency is high, but the energy consumption is large, and the regenerated active carbon also needs to be cooled and cleaned, thereby increasing the operation cost of the device. CN1522785A discloses an oil gas recovery method, which compresses, cools and adsorbs oil gas under a pressurized condition, and has the disadvantages of high energy consumption and difficulty in stable operation of a compressor when the oil gas amount to be treated is unstable, especially when the oil gas amount fluctuates greatly.
CN101342427A discloses a method for recovering oil gas by a condensation-adsorption combined process, wherein oil gas is cooled and condensed to realize condensation and separation of part of oil gas components, uncondensed oil gas is recovered by adsorption-pressure swing desorption, adsorption tail gas reaches the standard and is discharged, and the desorbed oil gas returns to a cooling device to be mixed with collected oil gas and enters a condenser. The recommended oil gas condensation temperature is-80-30 ℃, and the optimal temperature is-70-40 ℃. Oil gas components are recovered mainly by means of condensation and liquefaction, the condensation temperature is low, crystallization occurs in a condenser, and crystallization and condensation oil of water need to be removed periodically, so that two series of condensers are required to be switched for use; the total energy consumption of the device is larger, and the failure rate of the refrigeration equipment is higher. In addition, crystallization also occurs in the subsequent adsorption tanks, significantly reducing the service life of the adsorbent.
At present, a condensation method is mainly adopted to recover oil gas in oil product loading exhaust, the condensation temperature is-35 ℃ and-75 ℃, but the following problems mainly exist in the operation process of an oil gas treatment device adopting the condensation method: (1) The condensation system has serious frosting, and the ice blockage phenomenon exists at a switching valve or a pipeline for condensation and defrosting, so that the condensation system is difficult to stably operate; (2) In the defrosting process, hot gas defrosting is adopted, for example, hot nitrogen or refrigerant hot steam is adopted, and the refrigeration load of a condensing unit is increased by adopting hot nitrogen defrosting, so that the condensing energy consumption is increased; the defrosting is carried out by adopting the refrigerant and the hot steam, so that the stable operation of a refrigerating system is caused, the configuration of the refrigerating system is increased, and the operating power of a unit is increased.
Disclosure of Invention
Aiming at the defects of the oil gas recovery device by the condensation method in the prior art, the invention provides the oil gas recovery device by the condensation method. The device does not have the ice jam problem of system, and the device operation process has advantages such as reliable and stable, equipment are simple, safe energy-conservation.
The invention provides a condensation method oil gas recovery method in a first aspect.
A condensation method oil gas recovery method comprises the following steps:
(1) Providing a group of deep coolers, wherein each group is provided with two A/C deep coolers, and providing a pre-condenser B, an oil storage tank and a water storage tank;
(2) When the deep cooler A needs defrosting, shallow cold secondary refrigerant is introduced into the shell pass of the deep cooler A, and oil gas to be treated passes through the tube pass of the deep cooler A to obtain liquid water which enters a water storage tank;
(3) The oil gas after flowing through the deep cooler A enters a pipe pass of a pre-condenser B, and the oil gas is pre-cooled to 4-8 ℃ in the pre-condenser B by a shallow cold secondary refrigerant;
(4) Gas-liquid separation is carried out on the precooled oil gas, the obtained liquid water enters a water storage tank, and the separated gas enters a pipe pass C of the deep cooler; cooling the oil gas in a deep cooler C to-35-75 ℃ by using a deep cooling secondary refrigerant to realize oil gas condensation; carrying out gas-liquid separation on the condensed oil gas, enabling the condensate to enter an oil storage tank, and enabling the purified gas to enter the next processing unit for processing;
(5) When the deep cooler C needs defrosting, the shell pass medium of the deep cooler C is switched from deep cold secondary refrigerant to shallow cold secondary refrigerant, and the shell pass medium of the deep cooler A is switched from shallow cold secondary refrigerant to deep cold secondary refrigerant; switching oil gas to be treated to enter a tube pass of a chiller C, precooling the oil gas to be treated in the chiller C, and defrosting the chiller C at the same time;
(6) And liquid water obtained by defrosting the chiller C enters a water storage tank, and precooled gas flows through the precooler B and the chiller A in sequence to realize dehydration and oil gas recovery.
Further, the operating temperature of the shallow cold secondary refrigerant is 1-5 ℃; the operation temperature of the deep cooling refrigerating medium is-35 ℃ to-75 ℃.
Further, the oil gas precooled in the step (3) is subjected to gas-liquid separation in oil-gas separation spaces at two ends of a precondenser B.
In the method of the present invention, the refrigeration technology, the gas-liquid separation technology, and the like are well known to those skilled in the art.
In the invention, the shallow cold secondary refrigerant is used as a defrosting medium of the deep cooler A/C, and the cold energy in the heat exchanger is recovered while precooling the oil gas.
The invention provides a condensation method oil gas recovery device, which comprises a pre-condenser B, a deep cooler A/C, an oil storage tank, a water storage tank and the like; the tube side of the deep cooler A/C and the pre-condenser B is an oil-gas stroke, and the shell side is a secondary refrigerant stroke;
the gas interfaces at the two ends of the pre-condenser B are respectively connected with the gas interface at one end of the chiller A/C, and the gas interface at the other end of the chiller A/C is simultaneously communicated with an oil gas pipeline to be processed and a purified gas pipeline;
gas condensate outlets at two ends of the pre-condenser B are connected with inlets of the water storage tank;
gas condensate oil outlets at the other end of the deep cooler A/C which is not connected with the pre-condenser B are communicated with inlets of the oil storage tanks;
shell pass secondary refrigerant interfaces of the deep coolers A/C close to the two ends of the pre-condenser B are communicated with a shallow cold secondary refrigerant inlet pipe and a deep cold secondary refrigerant inlet pipe; the shell pass secondary refrigerant interface at the other end of the deep cooler A/C is communicated with both the shallow cold secondary refrigerant outlet pipe and the deep cold secondary refrigerant outlet pipe;
and one end of the shell pass of the pre-condenser B is communicated with the shallow cold secondary refrigerant inlet pipe, and the other end of the shell pass of the pre-condenser B is communicated with the shallow cold secondary refrigerant outlet pipe.
Furthermore, the pre-condenser B can adopt a single-shell-pass or double-shell-pass shell-and-tube heat exchanger, a plate heat exchanger, preferably a single-shell-pass or double-shell-pass heat exchanger; the A/C of the deep cooler adopts a single-tube-pass tubular heat exchanger. The heat exchangers are preferably horizontal.
Furthermore, end pipe boxes at two ends of the tube pass of the pre-condenser B are respectively shared with the end pipe box at one end of the tube pass of the deep cooler A/C. Furthermore, the pre-condenser B and the deep cooler A/C adopt an integrated structure. One typical integrated structure is: the pre-condenser B is of a horizontal U-shaped structure, and a tube pass end pipe box at one end of the deep cooler A, C is respectively communicated with the tube pass end pipe boxes at two ends of the pre-condenser B and shares the same.
Further, the other end gas interface of the deep cooler A/C is communicated with the oil gas pipeline to be treated and the purified gas pipeline at the same time. And each connecting pipeline is provided with a switching valve for the oil gas to be treated and the purified gas to enter and exit the chiller A/C, and the setting of the valve is well known by the technical personnel in the field.
Compared with the prior art, the oil gas recovery method and the oil gas recovery device by the condensation method have the following advantages:
1. in the method for recovering the oil gas by the condensation method, the oil gas to be treated enters the deep cooler in a switching manner, so that the continuous operation of the condensation method is realized, the shallow cold secondary refrigerant and the oil gas to be treated are used as defrosting media, the frosting cold energy is recovered, the energy consumption of the oil gas recovery device by the condensation method can be effectively reduced, and the energy consumption of the device can be reduced by more than 20%.
2. In the oil gas recovery device adopting the condensation method, the single pipe Cheng Woshi tubular heat exchanger is adopted as the deep cooler, the oil gas flows through the tube pass of the heat exchanger, and the defrosting liquid and the condensed liquid respectively enter the water storage tank and the oil storage tank along with the flowing direction of the gas, so that the problem of ice blockage of a condensation system is solved, and the running reliability of the device is improved.
3. In the oil gas recovery device by the condensation method, the oil gas to be treated is used as a defrosting medium, so that the oil gas condensation effect is improved, the heat exchange area of a pre-condenser can be reduced, and the device investment is reduced.
Drawings
FIG. 1 is a schematic flow chart of the oil-gas recovery method by condensation method of the present invention.
Detailed Description
The following examples further illustrate specific aspects of the present invention, but are not limited to the following examples.
The invention provides an oil gas recovery device by a condensation method. The device comprises a pre-condenser B, a deep cooler A/C, an oil storage tank 8, a water storage tank 7 and the like. Oil gas to be treated flows through the tube passes of the pre-condenser B and the deep cooler A/C; the secondary refrigerant flows through the shell sides of the pre-condenser B and the chiller A/C. And gas interfaces at two ends of the pre-condenser B are respectively connected with a gas interface at one end of the chiller A/C. And the other end gas interface of the condenser A/C which is not connected with the pre-condenser B is simultaneously communicated with the oil gas pipeline 1 to be processed and the purified gas pipeline 2. Gas condensate outlets at two ends of the pre-condenser B are connected to inlets of the water storage tank 7. And gas condensate oil outlets at the other ends of the deep coolers A/C which are not connected with the pre-condenser are communicated with inlets of the oil storage tanks 8. Shell pass secondary refrigerant interfaces of deep coolers A/C close to two ends of a pre-condenser B are communicated with a shallow cold secondary refrigerant inlet pipe 3 and a deep cold secondary refrigerant inlet pipe 4. And a secondary refrigerant interface at the other end of the A/C shell pass of the deep cooler is communicated with a shallow cold secondary refrigerant outlet pipe 5 and a deep cold secondary refrigerant outlet pipe 6. One end of the shell side of the pre-condenser B is communicated with a shallow cold secondary refrigerant inlet pipe 3, and the other end of the shell side of the pre-condenser B is communicated with a shallow cold secondary refrigerant outlet pipe 5.
In the oil gas recovery device by the condensation method, the pre-condenser B can adopt a single-shell-pass or double-shell-pass shell-and-tube heat exchanger or a plate heat exchanger; the A/C of the deep cooler adopts a single-tube-pass tubular heat exchanger. The heat exchanger adopts a horizontal structure.
With reference to fig. 1, the oil gas recovery method by condensation method of the present invention comprises the following steps:
the oil gas to be treated firstly enters a chiller A, flows through the chiller A and then enters a pre-condenser B. The oil gas is pre-cooled to 4-8 ℃ in the pre-condenser B by a shallow cold secondary refrigerant, and the pre-cooled oil gas is subjected to gas-liquid separation in oil-gas separation spaces of pipe boxes at two ends of the pre-condenser B. And the separated gas enters another chiller C, the oil gas is cooled to-35-75 ℃ in the chiller C by a cryogenic secondary refrigerant to realize oil gas condensation, the condensed oil gas enters a tube box at the tube pass end part of the chiller C to separate condensate, and the purified gas after gas-liquid separation enters the next processing unit for processing.
When the deep cooler C needs defrosting, switching oil gas to be treated to enter from the deep cooler C; meanwhile, the medium in the shell pass C of the deep cooler is switched from deep cooling secondary refrigerant to shallow cooling secondary refrigerant, the shallow cooling secondary refrigerant is used as a defrosting medium of the deep cooler, and meanwhile, the cold energy in the heat exchanger is recovered. And (3) pre-cooling the oil gas to be treated in the chiller C and defrosting the chiller C at the same time, wherein the defrosting liquid enters the water storage tank 7 along with the air flow, and the gas sequentially flows through the pre-condenser B and the chiller A to realize oil gas recovery. The pre-condenser B is cooled by adopting shallow cold secondary refrigerant, and the deep cooler A is condensed by adopting deep cold secondary refrigerant.
Example 1
In this embodiment, 500m of gasoline loading oil gas 3 The oil gas loaded on the truck is treated by the device, the pre-condenser and the deep cooler adopt a single-tube-pass tubular heat exchanger, the oil gas is pre-cooled to 5 ℃ to remove water and high-condensation-point organic matters, then the oil gas is deep-cooled to-75 ℃, the oil gas recovery rate can be 95 percent, and the energy consumption of the device can be reduced by 23 percent by adopting the switching operation of the two deep coolers.
Claims (9)
1. A condensation method oil gas recovery method comprises the following steps:
(1) Providing a group of deep coolers, wherein each group is provided with two A/C deep coolers, and providing a pre-condenser B, an oil storage tank and a water storage tank;
(2) When the deep cooler A needs defrosting, shallow cold secondary refrigerant is introduced into the shell pass of the deep cooler A, and oil gas to be treated passes through the tube pass of the deep cooler A to obtain liquid water which enters a water storage tank;
(3) The oil gas after flowing through the deep cooler A enters a pipe pass of a pre-condenser B, and the oil gas is pre-cooled to 4-8 ℃ in the pre-condenser B by a shallow cold secondary refrigerant;
(4) Gas-liquid separation is carried out on the precooled oil gas, the obtained liquid water enters a water storage tank, and the separated gas enters a pipe pass C of the deep cooler; cooling the oil gas in a deep cooler C to-35 to-75 ℃ by using a deep cooling secondary refrigerant to realize oil gas condensation; carrying out gas-liquid separation on the condensed oil gas, enabling the condensate to enter an oil storage tank, and enabling the purified gas to enter the next processing unit for processing;
(5) When the deep cooler C needs defrosting, the shell pass medium of the deep cooler C is switched from the deep cold secondary refrigerant to the shallow cold secondary refrigerant, and the shell pass medium of the deep cooler A is switched from the shallow cold secondary refrigerant to the deep cold secondary refrigerant; switching oil gas to be treated to enter a pipe pass of a deep cooler C, precooling the oil gas to be treated in the deep cooler C, and defrosting the deep cooler C;
(6) Liquid water obtained by defrosting of the chiller C enters a water storage tank, and precooled gas flows through a precooler B and the chiller A in sequence to realize dehydration and oil gas recovery;
and end pipe boxes at two ends of the pipe pass of the pre-condenser B are respectively shared with an end pipe box at one end of the pipe pass of the deep cooler A/C.
2. The oil and gas recovery method according to claim 1, wherein the operating temperature of the shallow cold coolant is 1 ℃ to 5 ℃, and the operating temperature of the deep cold coolant is-35 ℃ to-75 ℃.
3. The oil and gas recovery method according to claim 1, characterized in that the precondenser B employs a single shell pass or double shell pass shell-and-tube heat exchanger, a plate heat exchanger; the A/C of the deep cooler adopts a single-tube-pass tubular heat exchanger.
4. The oil gas recovery device by the condensation method is characterized by comprising a pre-condenser B, a deep cooler A/C, an oil storage tank and a water storage tank; the tube side of the deep cooler A/C and the pre-condenser B is an oil-gas stroke, and the shell side is a secondary refrigerant stroke;
the gas interfaces at the two ends of the pre-condenser B are respectively connected with the gas interface at one end of the chiller A/C, and the gas interface at the other end of the chiller A/C is simultaneously communicated with an oil gas pipeline to be processed and a purified gas pipeline; gas condensate outlets at two ends of the pre-condenser B are connected with inlets of the water storage tank;
gas condensate oil outlets at the other end of the deep cooler A/C which is not connected with the pre-condenser B are communicated with inlets of the oil storage tanks;
shell pass secondary refrigerant interfaces of the deep coolers A/C close to the two ends of the pre-condenser B are communicated with a shallow cold secondary refrigerant inlet pipe and a deep cold secondary refrigerant inlet pipe; the shell pass secondary refrigerant interface at the other end of the deep cooler A/C is communicated with both the shallow cold secondary refrigerant outlet pipe and the deep cold secondary refrigerant outlet pipe;
one end of the shell pass of the pre-condenser B is communicated with the shallow cold secondary refrigerant inlet pipe, and the other end of the shell pass of the pre-condenser B is communicated with the shallow cold secondary refrigerant outlet pipe;
the tube pass end part of one end of the deep cooler A and the deep cooler C respectively shares an end pipe box with the end parts of the two end pipe passes of the pre-condenser B.
5. The oil and gas recovery device according to claim 4, wherein the precondenser B adopts a single-shell-pass or double-shell-pass shell-and-tube heat exchanger or a plate heat exchanger, and the chiller A/C adopts a single-shell-and-tube heat exchanger.
6. The oil and gas recovery device according to claim 5, wherein the pre-condenser B and the deep cooler A/C are of a horizontal type structure.
7. The oil and gas recovery device according to claim 4, wherein the end headers on both ends of the tube pass of the pre-condenser B are respectively shared with the end header on one end of the tube pass of the chiller A/C.
8. The oil and gas recovery device according to claim 7, wherein the pre-condenser B and the chiller A/C are of an integrated structure.
9. The oil and gas recovery device according to claim 8, wherein said integrated structure is: the pre-condenser B is of a horizontal U-shaped structure, and a tube pass end part tube box at one end of the deep cooler A, C is respectively communicated with tube pass end part tube boxes at two ends of the pre-condenser B.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201911418148.6A CN113122302B (en) | 2019-12-31 | 2019-12-31 | Condensation method oil gas recovery method and device |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201911418148.6A CN113122302B (en) | 2019-12-31 | 2019-12-31 | Condensation method oil gas recovery method and device |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN113122302A CN113122302A (en) | 2021-07-16 |
| CN113122302B true CN113122302B (en) | 2023-04-07 |
Family
ID=76769203
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201911418148.6A Active CN113122302B (en) | 2019-12-31 | 2019-12-31 | Condensation method oil gas recovery method and device |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN113122302B (en) |
Family Cites Families (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN104857810B (en) * | 2014-02-23 | 2017-03-08 | 参化（上海）能源科技有限公司 | Gas condensation process and equipment |
| 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 |
| CN206082057U (en) * | 2016-10-18 | 2017-04-12 | 泸州松果文化创意有限公司 | Efficient vapor recovery system system of low power consuming |
| CN106742888A (en) * | 2016-12-15 | 2017-05-31 | 安徽科海压缩机制造有限公司 | The shallow cold recovery device of the supercharging of volatile organic steam in a kind of oil gas |
-
2019
- 2019-12-31 CN CN201911418148.6A patent/CN113122302B/en active Active
Also Published As
| Publication number | Publication date |
|---|---|
| CN113122302A (en) | 2021-07-16 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| USRE39826E1 (en) | Comprehensive natural gas processing | |
| CN103394267B (en) | A kind of device for recovering oil and gas in conjunction with condensation and absorption | |
| CN205461098U (en) | Oil -gas recovery processing device | |
| US11560523B2 (en) | Stage and system for compressing cracked gas | |
| EP3724578B1 (en) | Process integration for natural gas liquid recovery | |
| CN109749780B (en) | Device and method for recovering carbon dioxide in refinery dry gas by oil absorption and compression condensation method | |
| CN111575044B (en) | Indirect oil gas condensation recovery device and recovery process thereof | |
| CN108689381B (en) | Oil gas recovery system and recovery method for oil loading and unloading platform of refinery area | |
| CN111635777B (en) | Unsteady state oil gas recovery system | |
| CN105536282A (en) | Pressurizing multi-grade condensation type oil gas recycling method | |
| US20150253076A1 (en) | Method and apparatus for purifying a carbon dioxide-rich mixture at a low temperature | |
| CN204710058U (en) | A kind of industrial volatile organic matter gas concentration unit | |
| CN113122302B (en) | Condensation method oil gas recovery method and device | |
| CN106669355B (en) | Integrated oil gas recovery device based on image identification defrosting technology | |
| CN114437753B (en) | Condensing oil gas recovery method and device | |
| CN214809616U (en) | Oil gas recovery device | |
| CN220485639U (en) | Natural gas hydrocarbon removal equipment | |
| US3116136A (en) | Gas drying and separation | |
| US11892235B2 (en) | Method and system for processing natural gas | |
| CN221319888U (en) | Absorption stabilizing system of catalytic cracking device | |
| CN112299942B (en) | Method and system for recovering carbon dioxide fraction in refinery dry gas | |
| CN216986350U (en) | Energy-saving device is retrieved to outer cold source condensing VOCs | |
| US20210381757A1 (en) | Gas stream component removal system and method | |
| CN111151099A (en) | Oil gas low-temperature absorption process method | |
| CN117511598A (en) | Absorption stabilizing system of catalytic cracking device |
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 | ||
| TR01 | Transfer of patent right |
Effective date of registration: 20231128 Address after: 100728 No. 22 North Main Street, Chaoyang District, Beijing, Chaoyangmen Patentee after: CHINA PETROLEUM & CHEMICAL Corp. Patentee after: Sinopec (Dalian) Petrochemical Research Institute Co.,Ltd. Address before: 100728 No. 22 North Main Street, Chaoyang District, Beijing, Chaoyangmen Patentee before: CHINA PETROLEUM & CHEMICAL Corp. Patentee before: DALIAN RESEARCH INSTITUTE OF PETROLEUM AND PETROCHEMICALS, SINOPEC Corp. |
|
| TR01 | Transfer of patent right |