CN111394116A - Oil gas recovery method and device - Google Patents
Oil gas recovery method and device Download PDFInfo
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- CN111394116A CN111394116A CN201910740666.3A CN201910740666A CN111394116A CN 111394116 A CN111394116 A CN 111394116A CN 201910740666 A CN201910740666 A CN 201910740666A CN 111394116 A CN111394116 A CN 111394116A
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- 238000011084 recovery Methods 0.000 title claims abstract description 59
- 238000000034 method Methods 0.000 title claims abstract description 44
- 238000000926 separation method Methods 0.000 claims abstract description 166
- 239000007788 liquid Substances 0.000 claims abstract description 115
- QQONPFPTGQHPMA-UHFFFAOYSA-N propylene Natural products CC=C QQONPFPTGQHPMA-UHFFFAOYSA-N 0.000 claims abstract description 93
- 125000004805 propylene group Chemical group [H]C([H])([H])C([H])([*:1])C([H])([H])[*:2] 0.000 claims abstract description 93
- 239000007791 liquid phase Substances 0.000 claims abstract description 90
- 239000012071 phase Substances 0.000 claims abstract description 70
- 239000004215 Carbon black (E152) Substances 0.000 claims abstract description 51
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 51
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 51
- 238000006477 desulfuration reaction Methods 0.000 claims abstract description 39
- 230000023556 desulfurization Effects 0.000 claims abstract description 39
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 claims abstract description 33
- 229910052799 carbon Inorganic materials 0.000 claims abstract description 33
- LSDPWZHWYPCBBB-UHFFFAOYSA-N Methanethiol Chemical compound SC LSDPWZHWYPCBBB-UHFFFAOYSA-N 0.000 claims abstract description 21
- 150000001412 amines Chemical class 0.000 claims abstract description 16
- 239000002250 absorbent Substances 0.000 claims description 119
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 claims description 118
- 230000002745 absorbent Effects 0.000 claims description 116
- 238000010521 absorption reaction Methods 0.000 claims description 65
- 239000001294 propane Substances 0.000 claims description 59
- 238000000605 extraction Methods 0.000 claims description 40
- 239000012535 impurity Substances 0.000 claims description 37
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 36
- 238000010992 reflux Methods 0.000 claims description 32
- 238000005406 washing Methods 0.000 claims description 12
- 239000003513 alkali Substances 0.000 claims description 10
- 238000005520 cutting process Methods 0.000 claims description 10
- 239000000463 material Substances 0.000 claims description 10
- 238000001816 cooling Methods 0.000 claims description 9
- 239000000203 mixture Substances 0.000 claims description 8
- 238000009835 boiling Methods 0.000 claims description 5
- 238000001035 drying Methods 0.000 claims description 5
- 238000011144 upstream manufacturing Methods 0.000 claims description 5
- 239000003518 caustics Substances 0.000 claims description 4
- 230000018044 dehydration Effects 0.000 claims description 4
- 238000006297 dehydration reaction Methods 0.000 claims description 4
- 238000002156 mixing Methods 0.000 claims description 4
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 abstract description 29
- YNQLUTRBYVCPMQ-UHFFFAOYSA-N Ethylbenzene Chemical compound CCC1=CC=CC=C1 YNQLUTRBYVCPMQ-UHFFFAOYSA-N 0.000 abstract description 20
- 229910002092 carbon dioxide Inorganic materials 0.000 abstract description 20
- PPBRXRYQALVLMV-UHFFFAOYSA-N Styrene Chemical compound C=CC1=CC=CC=C1 PPBRXRYQALVLMV-UHFFFAOYSA-N 0.000 abstract description 16
- 239000001569 carbon dioxide Substances 0.000 abstract description 14
- 230000000694 effects Effects 0.000 abstract description 6
- 239000006260 foam Substances 0.000 abstract description 3
- 238000005187 foaming Methods 0.000 abstract description 3
- 239000000126 substance Substances 0.000 abstract 1
- 239000007789 gas Substances 0.000 description 122
- VGGSQFUCUMXWEO-UHFFFAOYSA-N Ethene Chemical compound C=C VGGSQFUCUMXWEO-UHFFFAOYSA-N 0.000 description 11
- 239000005977 Ethylene Substances 0.000 description 11
- 238000005265 energy consumption Methods 0.000 description 9
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 description 8
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 description 7
- 229910000037 hydrogen sulfide Inorganic materials 0.000 description 7
- UHOVQNZJYSORNB-UHFFFAOYSA-N Benzene Chemical compound C1=CC=CC=C1 UHOVQNZJYSORNB-UHFFFAOYSA-N 0.000 description 6
- 238000004523 catalytic cracking Methods 0.000 description 6
- 230000000087 stabilizing effect Effects 0.000 description 6
- 239000001257 hydrogen Substances 0.000 description 4
- 229910052739 hydrogen Inorganic materials 0.000 description 4
- 238000004519 manufacturing process Methods 0.000 description 4
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 description 3
- 230000003009 desulfurizing effect Effects 0.000 description 3
- 238000010586 diagram Methods 0.000 description 3
- 238000004939 coking Methods 0.000 description 2
- 230000007797 corrosion Effects 0.000 description 2
- 238000005260 corrosion Methods 0.000 description 2
- 238000005336 cracking Methods 0.000 description 2
- 230000003111 delayed effect Effects 0.000 description 2
- 238000003795 desorption Methods 0.000 description 2
- AMXOYNBUYSYVKV-UHFFFAOYSA-M lithium bromide Chemical compound [Li+].[Br-] AMXOYNBUYSYVKV-UHFFFAOYSA-M 0.000 description 2
- -1 polyethylene Polymers 0.000 description 2
- 238000012545 processing Methods 0.000 description 2
- 239000003507 refrigerant Substances 0.000 description 2
- 239000002904 solvent Substances 0.000 description 2
- PVXVWWANJIWJOO-UHFFFAOYSA-N 1-(1,3-benzodioxol-5-yl)-N-ethylpropan-2-amine Chemical compound CCNC(C)CC1=CC=C2OCOC2=C1 PVXVWWANJIWJOO-UHFFFAOYSA-N 0.000 description 1
- QMMZSJPSPRTHGB-UHFFFAOYSA-N MDEA Natural products CC(C)CCCCC=CCC=CC(O)=O QMMZSJPSPRTHGB-UHFFFAOYSA-N 0.000 description 1
- 239000004698 Polyethylene Substances 0.000 description 1
- 239000006096 absorbing agent Substances 0.000 description 1
- 230000002411 adverse Effects 0.000 description 1
- 229910002090 carbon oxide Inorganic materials 0.000 description 1
- 238000003889 chemical engineering Methods 0.000 description 1
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- 238000011161 development Methods 0.000 description 1
- 238000010828 elution Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 150000002431 hydrogen Chemical class 0.000 description 1
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- 229920000573 polyethylene Polymers 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 238000011027 product recovery Methods 0.000 description 1
- 238000007670 refining Methods 0.000 description 1
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- 238000001179 sorption measurement Methods 0.000 description 1
- 230000006641 stabilisation Effects 0.000 description 1
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Classifications
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- 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
-
- 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
- C10G53/00—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes
- C10G53/02—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes plural serial stages only
- C10G53/12—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes plural serial stages only including at least one alkaline treatment step
-
- 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
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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 invention belongs to the field of chemical industry, and particularly discloses a method and a device for recovering oil gas, wherein the method has the advantages of simple process, mild operating conditions and low cold consumption, can realize the high-efficiency separation and recovery of light gasoline, heavy gasoline, carbon two, carbon three and carbon four components by using less equipment, particularly can realize the high-efficiency separation and recovery of the carbon two, the carbon three and the carbon four components, basically does not contain propylene in a recovered carbon dioxide product, and can be directly used for preparing ethylbenzene/styrene by being sent to the downstream; the gas phase and the liquid phase are adopted for desulfurization and mercaptan removal respectively, and the gas phase is subjected to desulfurization and mercaptan removal under high pressure, so that the equipment volume is small, the investment is low, and the desulfurization effect is good; meanwhile, the content of heavy hydrocarbon in the gas phase is reduced, the heavy hydrocarbon can be prevented from being condensed into the amine liquid, foam entrainment of a desulfurization device caused by the foaming of the amine liquid can be effectively avoided, and the stable operation of the device is ensured.
Description
Technical Field
The invention belongs to the field of oil refining and chemical engineering, and particularly relates to a method and a device for recovering oil gas, in particular to a device and a method for recovering oil gas in processes with high gas yield, such as catalytic cracking, delayed coking and the like.
Background
Light hydrocarbon refers to the components of methane, ethane, ethylene, propane, propylene, carbon and the like obtained in the petrochemical process, and the light hydrocarbon separation process is always the key point of attention of the petrochemical process. Among them, the separation process between carbon two, carbon three and carbon four is mature, and the rectification method is usually adopted. Methane, due to its low boiling point, requires cooling to temperatures of-100 ℃ and below, i.e. cryogenic separation, if a rectification process is used to separate methane and carbon dioxide, is commonly used in ethylene plants, which is very costly and costly. Therefore, the separation of methane has been the focus of attention on the light hydrocarbon separation process, and the development of the light hydrocarbon separation process technology and the design of the process flow are all performed around the separation of methane.
The prior catalytic cracking process usually adopts absorption stabilization to recover liquefied gas (C3/C4) components and realize the liquefied gas components and dry gas (H)2/C1/C2). The catalytic cracking process has high dry gas yield, the content of the C2 component in the dry gas can reach 25-40 wt%, the dry gas mainly comprises ethylene and ethane, the ethylene can be used for producing polyethylene, styrene and the like, the ethane can be used for producing ethylene by cracking, the yield of the ethylene by cyclic cracking reaches 80%, and the ethylene is rich in hydrogen. Therefore, the recovery of C2 resource in dry gas is of great interest. Generally, the carbon dioxide resource returned can be sent to an ethylene plant separation unit to obtain ethylene and ethane, and can also be sent to a downstream plant to prepare ethylbenzene/styrene. The prior art focuses on recovering carbon dioxide in dry gas by adopting an absorption method, and the process method has the following defects:
(1) the dry gas and the carbon four components are separated for the second time: and the dry gas and the liquefied gas are separated in the absorption stabilizing part, the carbon four is adopted to absorb the carbon four in the carbon four recovery part, the carbon four and the dry gas are mixed again, and then the separation is carried out.
(2) The absorption stabilizing system adopts stable gasoline as an absorbent to recover liquefied gas components, and the catalytic cracking process has the advantages that the yield of the liquefied gas components is high, the gasoline circulates among the gasoline absorption tower, the ethane desorption tower and the stabilizing tower, the circulating amount is large, the temperature levels of the ethane desorption tower and the stabilizing tower are high, the heat load of a reboiler at the bottom of the tower is large, and the energy consumption is high.
(3) The whole process flow is longer, and the investment and the energy consumption are correspondingly increased. The invention is provided for recovering light hydrocarbon components such as C2/C3/C4 and the like in a catalytic cracking process, simplifying a separation process and reducing investment and energy consumption.
(4) When the recovered carbon dioxide product is sent to an ethylene plant separation unit, part of heavy components such as propylene and the like in the carbon dioxide product can be recovered through the ethylene separation unit; however, when the recovered carbon dioxide product is sent to downstream ethylbenzene production, the propylene component contained in the recovered carbon dioxide product can bring many adverse effects to ethylbenzene production, which not only greatly increases the consumption of benzene, but also directly affects the quality of ethylbenzene and styrene products. Due to the low boiling point of the carbon-two component, the separation of the carbon-two and carbon-three components usually requires temperatures of-5 to-20 ℃ to be reached, for which dehydration and CO removal are required2The treatment is carried out, and a refrigerant with lower temperature grade is needed, so the investment and the energy consumption are large.
(5) The prior art carries out desulfurization and sweetening on the dry gas and the liquefied gas which are stably absorbed, H2S and mercaptan are circulated in the whole absorption stabilizing system, and related corrosion problems can be caused, and H exists in the whole absorption stabilizing system2S leakage may present a safety issue.
Disclosure of Invention
The invention aims at providing a method and a device for recovering oil gas, which have simple process flow and mild operation conditions, and can realize the high-efficiency separation and recovery of light and heavy gasoline, carbon two, carbon three and carbon four components; meanwhile, the gas phase and the liquid phase are respectively adopted for desulfurization and mercaptan removal, so that the desulfurization effect is better, and the operation is more flexible.
In order to achieve the above object, the present invention provides a method for oil and gas recovery, the method comprising:
(1) first gas-liquid separation: oil gas from an upstream device is condensed and cooled and then sent to a gas-liquid separation tank I for gas-liquid separation, a liquid phase at the bottom of the tank is pressurized and sent to a light and heavy gasoline cutting tower, and a gas phase at the top of the tank is pressurized by a compressor and then sent to the light and heavy gasoline cutting tower;
(2) separating light gasoline and heavy gasoline: the material from the gas-liquid separation tank I enters a light and heavy gasoline separation tower, the gas phase distilled from the tower top is condensed and enters a tower top reflux tank, the gas phase at the top of the tower top reflux tank is compressed and then sent to a light hydrocarbon-light gasoline separation tower, the liquid phase at the bottom of the tank is pressurized and then sent to the light hydrocarbon-light gasoline separation tower, and at least part of the liquid phase at the bottom of the light and heavy gasoline separation tower is extracted as a heavy gasoline product;
(3) light hydrocarbon-light gasoline separation: the material flow from the top reflux tank of the light and heavy gasoline separation tower enters a light hydrocarbon-light gasoline separation tower, the gas phase distilled from the top of the tower enters a top reflux tank, the gas phase at the top of the top reflux tank is compressed and cooled and then sent to a gas-liquid separation tank II, the liquid phase at the bottom of the tank is pressurized and then sent to the gas-liquid separation tank II, and the liquid phase at the bottom of the tank is extracted as light gasoline;
(4) second gas-liquid separation: after the materials are mixed and gas-liquid balanced in the gas-liquid separation tank II, the gas phase and the liquid phase are separated again, and then impurities are respectively removed;
(5) gas-phase impurity removal: the gas phase on the top of the gas-liquid separation tank II is sequentially subjected to H removal in a rich gas desulfurization tower by taking lean amine liquid as an absorbent2S and CO2Removing mercaptan in a rich gas alkaline tower by taking alkali liquor as an absorbent, and then sending the rich gas alkaline tower to a cooler;
(6) liquid phase impurity removal: the liquid phase at the bottom of the tank separated by the gas-liquid separation tank II is sequentially subjected to H removal in a liquid hydrocarbon desulfurization tower2S and CO2After mercaptan is removed in the liquid hydrocarbon mercaptan removal reactor, the liquid hydrocarbon mercaptan removal reactor is sent to a cooler;
(7) and (3) cooling: mixing and cooling the gaseous light hydrocarbon and the liquid light hydrocarbon which are subjected to impurity removal in a cooler, and then sending the mixture to a feeding tank;
(8) feeding: after the mixture flow from the cooler is mixed, pre-absorbed and gas-liquid balanced in a feeding tank, the gas phase at the top of the tank is sent to an absorption tower, and the liquid phase at the bottom of the tank is sent to a separation unit;
(9) absorption: in the absorption tower, the mixed C4 is used as an absorbent to absorb components with the content of C2 and above C2 in a gas phase from the top of a feed tank, and simultaneously, part of methane is absorbed, the gas phase at the top of the absorption tower is sent to a downstream device, and a liquid phase at the bottom of the absorption tower is returned to a cooler;
(10) separation: the liquid phase from the bottom of the feed tank is further separated into C2, C3 and C4 components through a demethanizer, a deethanizer, a depropanizer and an optional propylene rectifying tower in a separation unit, wherein, propane and/or mixed C4 in the deethanizer is used as absorbent to separate C2 components, C2 and C3 components are respectively extracted as C2 and C3 products, at least one part of C4 components is sent to the absorption tower and the optional deethanizer as mixed C4 absorbent, and the rest is extracted as mixed C4 product.
The invention has wide application range, and the oil gas (including H) in the common processes with higher gas yield such as catalytic cracking, delayed coking and the like in chemical production2C1-C4, gasoline components and minor amounts of non-hydrocarbon components) can be recovered using the apparatus of the present invention.
In the invention, oil gas from an upstream device is condensed and cooled and then sent to a gas-liquid separation tank I for gas-liquid separation, a liquid phase at the bottom of the tank is pressurized by a pump and sent to a light and heavy gasoline cutting tower, a gas phase at the top of the tank is pressurized by a compressor and then sent to the light and heavy gasoline cutting tower, wherein the compressor is divided into a plurality of sections, and the liquid phase generated between the compression sections is sent to the light and heavy gasoline cutting tower. The heavy gasoline is separated from the oil gas in a light and heavy gasoline cutting tower, and then the light gasoline is separated in a light hydrocarbon-light gasoline separation tower, so that the light and heavy gasoline is separated in advance, the light and heavy gasoline does not participate in a downstream light hydrocarbon separation process, and the process energy consumption can be greatly reduced, preferably, the operating temperature at the top of the light and heavy gasoline separation tower is 60-85 ℃, the operating temperature at the bottom of the light and heavy gasoline separation tower is 140-190 ℃, and the operating pressure is 0.25-0.5 MPaG; the operating temperature of the top of the light hydrocarbon-light gasoline separating tower is 55-80 ℃, and the operating pressure is 1.0-1.35 MPaG; the initial boiling point of the heavy gasoline is 60-85 ℃, and the dry point of the light gasoline is 65-90 ℃.
In the invention, in order to meet the requirement of related product recovery, impurity removal is required before next separation, and the impurity removal mainly comprises amine elution H2S and alkali washing to remove mercaptan. Because the effects of gas phase desulfurization and mercaptan removal are better under high pressure, and the volume of desulfurization equipment under high pressure is smaller, the compressed gas phase in the gas-liquid separation tank II and the pressurized liquid phase are mixed and subjected to gas-liquid equilibrium, the gas phase and the liquid phase are separated again, and then impurities are respectively removed. Preferably, the operating temperature of the gas-liquid separation tank II is 35-45 ℃, and the operating pressure is 2.3-2.9 MPaG. Because the content of heavy hydrocarbon in the separated gas phase is less, the amount of heavy hydrocarbon condensed into the amine liquid is less when the desulfurization is carried out, and the problem that the foam entrainment of the desulfurization device caused by the foaming of the amine liquid influences the stable operation of the device is effectively avoided.
In the present invention, in order to meet the requirements of the recovery of the relevant products, it is preferable that the amine elute H2S adopts a compound amine liquid solvent (namely a modified solvent based on MDEA) and carries out H simultaneously2S and CO2In which H is2S can be removed to less than 10ppmv, CO2The removal efficiency can reach 90-95 wt%, and CO in material flow entering the alkaline washing mercaptan removal reactor is effectively reduced2And further reducing the consumption of alkali liquor.
According to the invention, preferably, the operation temperature of the rich gas desulfurization tower is 35-45 ℃, and the operation pressure is 2.2-2.8 MPaG; the operation temperature of the rich gas alkaline washing tower is 35-45 ℃, and the operation pressure is 2.2-2.8 MPaG; the operating temperature of the liquid hydrocarbon desulfurization tower is 35-45 ℃, and the operating pressure is 3.0-3.5 MPaG.
In the invention, the gas-phase component and the liquid-phase component after impurity removal are cooled before being sent into the feeding tank, and the cooled liquid phase and the cooled and compressed gas phase are both sent into the feeding tank, preferably, the operating temperature of the feeding tank is 5-25 ℃, and the operating pressure is 2.2-2.8 MPaG.
According to the present invention, preferably, according to the present invention, the operation temperature of the absorption tower is 5 to 25 ℃ and the operation pressure is 2.1 to 2.7 MPaG. In the invention, the absorbent mixed with the C4 absorbent adopted by the absorption tower comes from the bottom of the depropanization tower, is a self-balanced C4 component in the system and does not need to be introduced from the outside of the system.
According to the invention, preferably, said separation in step (10) comprises one of the following three modes:
in a first mode, the separating step sequentially includes:
demethanization: removing methane from the liquid phase at the bottom of the feed tank in a demethanizer, simultaneously removing a small part of components with the content of C2 and above C2, sending the gas phase at the top of the demethanizer to a cooler, and sending the liquid phase at the bottom of the demethanizer to a deethanizer;
deethanizing: separating C2 component from liquid phase at the bottom of the demethanizer in a deethanizer by taking propane as an absorbent, optionally treating the separated mixed C2 component by impurities, and then extracting the component as a mixed C2 product, wherein the liquid phase components at the bottom of the demethanizer, which are more than C3 and C3, are sent to the depropanizer;
depropanizing: further separating liquid phase components from the bottom of the deethanizer in the depropanizer, extracting separated C3 components from the upper part of the depropanizer, sending at least one part of the bottom components to an absorption tower as a mixed C4 absorbent, and extracting the rest as a mixed C4 product;
further preferably, the separating further comprises:
and (3) propylene rectification: c3 components from the upper part of the depropanizing tower are further rectified in a propylene rectifying tower, the gas phase at the top of the propylene rectifying tower is taken out as a propylene product after being cooled, at least one part of the liquid phase at the bottom of the propylene rectifying tower is taken out as a propane product, and the rest part of the liquid phase is taken as a propane absorbent after being heated and then sent to the deethanizing tower;
in a second mode, the separating step sequentially comprises:
demethanization: removing methane from the liquid phase at the bottom of the feed tank in a demethanizer, simultaneously removing a small part of components with the content of C2 and above C2, sending the gas phase at the top of the demethanizer to a cooler, and sending the liquid phase at the bottom of the demethanizer to a deethanizer;
deethanizing: separating C2 components from a liquid phase at the bottom of the demethanizer in a deethanizer by taking mixed C4 as an absorbent, optionally treating impurities of the separated mixed C2 components at the top of the deethanizer, extracting the treated components as a mixed C2 product, and distributing liquid phase components above C3 and C3 at the bottom of the deethanizer;
depropanizing: further separating liquid phase components from the bottom of the deethanizer in the depropanizer, extracting separated C3 components from the upper part of the depropanizer, at least one part of the tower bottom components serving as a mixed C4 absorbent is respectively sent to an absorption tower and the deethanizer, and the rest part serving as a mixed C4 product is extracted;
further preferably, the separating further comprises:
and (3) propylene rectification: c3 component from the upper part of the depropanizing tower is further rectified in a propylene rectifying tower, the gas phase at the top of the propylene rectifying tower is taken out as a propylene product after being cooled, and the liquid phase at the bottom of the propylene rectifying tower is taken out as a propane product;
in a third mode, the separating step sequentially comprises:
demethanization: removing methane from the liquid phase at the bottom of the feed tank in a demethanizer, simultaneously removing a small part of components with the carbon number of C2 and more than C2, sending the gas phase at the top of the demethanizer to a cooler, and sending the liquid phase at the bottom of the demethanizer to a depropanizer;
depropanizing: separating liquid phase components from the bottom of the demethanizer in a depropanizer, extracting components with the C3 and the C3 or less from the upper part of the depropanizer, optionally drying, and then sending to the depropanizer, wherein at least one part of the tower bottom components is taken as a mixed C4 absorbent and sent to an absorption tower, and the rest is taken as a mixed C4 product;
deethanizing: the gas phase from the upper part of the depropanizing tower is further separated in the deethanizing tower by taking propane as an absorbent, the separated mixed C2 component at the top of the tower is extracted as a mixed C2 product after being optionally subjected to impurity treatment, and the liquid phase at the bottom of the tower is extracted as a mixed C3 component;
further preferably, the separating further comprises:
and (3) propylene rectification: the mixed C3 component from the bottom of the deethanizer is further rectified in a propylene rectifying tower, the gas phase at the top of the propylene rectifying tower is cooled and then extracted as a propylene product, at least one part of the liquid phase at the bottom of the tower is extracted as a propane product, and the rest part of the liquid phase is sent to the deethanizer as a propane absorbent.
When the deethanizer adopts a propane absorbent or a mixed C4 absorbent to separate C2 components, the separated C2 components basically do not carry propylene, and only contain 15-18 mol% of propane or 10-13 mol% of C4, at the moment, the lowest temperature at the top of the deethanizer is only 15 ℃, drying facilities are not needed, and the requirements can be met by conventional lithium bromide refrigeration. Because the content of propylene in the C2 component is greatly reduced, the propylene can be directly sent to the preparation of ethylbenzene without arranging other impurity removal facilities, and preferably, the operation temperature at the top of the deethanizer is 15-30 ℃, and the operation pressure is 2.6-3.2 MPaG; the propane absorbent and/or mixed C4 absorbent comes from propane and/or mixed C4 components from self-balancing in the system, and does not need to be introduced from the outside of the system.
In the invention, the separated mixed C3 component can be further rectified to obtain a propylene product and a propane product, preferably, the operating temperature of the propylene rectifying tower is 45-60 ℃, and the operating pressure is 1.8-2.0 MPaG.
To further recover the mixed C4 absorbent entrained in the absorber overhead stream, preferably, the process further comprises:
(11) and (3) recovering the absorbent: in the absorbent recovery tower, part of the heavy gasoline product extracted in the step (2) is used as an absorbent to absorb components of C4 and above C4 in a gas phase from the top of the absorption tower, and simultaneously absorbs a small amount of components of C2/C3, the gas phase at the top of the absorbent recovery tower is extracted as a dry gas, and a liquid phase at the bottom of the absorbent recovery tower is returned to the light and heavy gasoline separation tower, further preferably, the operating temperature of the absorbent recovery tower is 15-40 ℃, and the operating pressure is 2.1-2.7 MPaG.
In another aspect, the present invention provides an apparatus for recovering oil and gas, the apparatus comprising: the system comprises an oil-gas feeding pipeline, a gas-liquid separation tank I, a compressor I, a light and heavy gasoline separation tower, a compressor II, a light hydrocarbon-light gasoline separation tower, a compressor III, a cooler I, a gas-liquid separation tank II, a rich gas desulfurization tower, a rich gas alkaline washing tower, a liquid hydrocarbon desulfurization tower, a liquid hydrocarbon sweetening reactor, a cooler II, a feeding tank, an absorption tower and a separation unit;
the oil-gas feeding pipeline is connected with an inlet of a gas-liquid separation tank I, the top of the gas-liquid separation tank I is sequentially connected with a compressor I and a light-heavy gasoline separation tower, and the bottom of the gas-liquid separation tank I is connected with the light-heavy gasoline separation tower;
the top of the light and heavy gasoline separation tower is provided with a reflux tank I, the top of the reflux tank I is sequentially connected with a compressor II and a light hydrocarbon-light gasoline separation tower, the bottom of the tank is connected with a booster pump and then connected with the light hydrocarbon-light gasoline separation tower, and the bottom of the light and heavy gasoline separation tower is provided with a heavy gasoline extraction pipeline;
a reflux tank II is arranged at the top of the light hydrocarbon-light gasoline separation tower, the top of the reflux tank II is sequentially connected with a compressor III, a cooler I and a gas-liquid separation tank II, and the bottom of the reflux tank II is connected with a booster pump and then connected with the gas-liquid separation tank II;
the top of the gas-liquid separation tank II is sequentially connected with a rich gas desulfurization tower, a rich gas alkaline washing tower and a cooler II, and the bottom of the tank is sequentially connected with a liquid hydrocarbon desulfurization tower, a liquid hydrocarbon sweetening reactor and the cooler II;
the upper part of the rich gas desulfurization tower is provided with a lean amine liquid feeding pipeline, and the upper part of the rich gas caustic tower is provided with an alkali liquid feeding pipeline;
the cooler II is connected with the feeding tank;
the top of the feeding tank is connected with the absorption tower, and the bottom of the tank is connected with the separation unit;
the top of the absorption tower is connected with a downstream device, the bottom of the absorption tower is connected with a cooler II, and the upper part of the absorption tower is provided with a mixed C4 absorbent feeding pipeline;
the separation unit includes: a demethanizer, deethanizer, depropanizer, and optionally a propylene rectification column; the top of the demethanizer is connected with a cooler II; a mixed C2 produced pipeline is arranged at the top of the deethanizer, an impurity treatment unit is optionally arranged on the mixed C2 produced pipeline, and a propane or mixed C4 absorbent feeding pipeline is arranged at the upper part of the deethanizer; the bottom of the depropanizing tower is provided with a mixed C4 product extraction pipeline, the mixed C4 product extraction pipeline is divided into two branches, and one branch is used as a mixed C4 absorbent feeding pipeline. In the present invention, the further separation of the components C4 and C4 is carried out in a separation unit, which may preferably be a demethanizer column connected at the top to cooler ii and at the bottom to a deethanizer; a mixed C2 extraction pipeline is arranged at the top of the deethanizer, an impurity treatment unit is optionally arranged on the mixed C2 extraction pipeline, the bottom of the deethanizer is connected with the depropanizer, and a propane absorbent feeding pipeline is arranged at the upper part of the deethanizer; the upper part of the depropanizing tower is provided with a mixed C3 produced pipeline, the mixed C3 produced pipeline is optionally connected with the propylene rectifying tower, the bottom of the depropanizing tower is provided with a mixed C4 product produced pipeline, the mixed C4 product produced pipeline is divided into two branches, and one branch is used as a mixed C4 absorbent feeding pipeline; preferably, a propylene product extraction pipeline is arranged at the top of the propylene rectifying tower, a propane product extraction pipeline is arranged at the bottom of the propylene rectifying tower, the propane product extraction pipeline is divided into two branches, and one branch is used as a propane absorbent feeding pipeline; or preferably, the top of the demethanizer is connected with a cooler II, and the bottom of the demethanizer is connected with a deethanizer; a mixed C2 produced pipeline is arranged at the top of the deethanizer, an impurity treatment unit is optionally arranged on the mixed C2 produced pipeline, the bottom of the deethanizer is connected with the depropanizer, and a mixed C4 absorbent feeding pipeline is arranged at the upper part of the deethanizer; a mixed C3 produced pipeline is arranged at the upper part of the depropanizing tower, the mixed C3 produced pipeline is optionally connected with the propylene rectifying tower, a mixed C4 product produced pipeline is arranged at the bottom of the depropanizing tower, the mixed C4 product produced pipeline is divided into two branches, one branch is used as a mixed C4 absorbent feeding pipeline and is respectively connected with the absorption tower and the deethanizing tower; further preferably, a propylene product extraction pipeline is arranged at the top of the propylene rectifying tower, and a propane product extraction pipeline is arranged at the bottom of the propylene rectifying tower; the top of the demethanizer can also be preferably connected with a cooler II, and the bottom of the demethanizer is connected with a depropanizer; the upper part of the depropanizing tower is connected with a drying unit optionally and then connected with a deethanizing tower, a mixed C4 product extraction pipeline is arranged at the bottom of the depropanizing tower, the mixed C4 product extraction pipeline is divided into two branches, and one branch is used as a mixed C4 absorbent feeding pipeline; a mixed C2 produced pipeline is arranged at the top of the deethanizer, an impurity treatment unit is optionally arranged on the mixed C2 produced pipeline, a mixed C3 produced pipeline is arranged at the bottom of the deethanizer, the mixed C3 produced pipeline is optionally connected with a propylene rectifying tower, and a propane absorbent feeding pipeline is arranged at the upper part of the deethanizer; further preferably, a propylene product extraction pipeline is arranged at the top of the propylene rectifying tower, a propane product extraction pipeline is arranged at the bottom of the propylene rectifying tower, the propane product extraction pipeline is divided into two branches, and one branch is used as a propane absorbent feeding pipeline.
According to the present invention, preferably, the downstream apparatus further comprises an absorbent recovery column; the top of the absorbent recovery tower is provided with a dry gas extraction pipeline, the bottom of the absorbent recovery tower is connected with a light and heavy gasoline separation tower, the upper part of the absorbent recovery tower is provided with a heavy gasoline absorbent feeding pipeline, the heavy gasoline extraction pipeline of the light and heavy gasoline separation tower is divided into two branches, and one branch is used as the heavy gasoline absorbent feeding pipeline.
In order to maintain the operating temperature of the whole tower uniform and ensure the absorption effect, the absorption tower is preferably provided with 2-5 middle-section refluxes, a condenser is not required to be arranged at the top of the absorption tower, a reboiler is not required to be arranged at the bottom of the absorption tower, the gas phase from a feeding tank is fed from the bottom of the absorption tower, and the absorbent is fed from the top of the absorption tower.
According to the invention, preferably, the top of the demethanizer is not provided with a condenser, the bottom of the demethanizer is provided with a reboiler, and the liquid phase from the feeding tank is fed from the top of the demethanizer; the apparatus does not include a dehydration apparatus.
Compared with the prior art, the invention has the following advantages:
(1) the invention separates the components below C4 and C4 from the light and heavy gasoline components, and does not need to adopt gasoline to circularly absorb the liquefied gas components, thereby greatly reducing the gasoline circulation amount and reducing the energy consumption of the whole separation process.
(2) The invention has simple flow, mild operation conditions and less cold consumption, can realize the separation and recovery of light and heavy gasoline and light hydrocarbon in oil gas by using less equipment, and particularly can realize the high-efficiency separation and recovery of C2, C3 and C4 components; and secondary separation process does not exist between the carbon two and each component, and meanwhile, the total recovery rate of the carbon two component can be ensured to be more than 98 wt%, the recovery rate of the propylene component can be more than 99 wt%, the content of methane in the recovered carbon two is not more than 1 vol%, and the content of ethane in the recovered carbon three component is not more than 200 ppmv.
(3) The deethanizer of the invention adopts propane or mixed C4 absorbent to separate C2 component, the separated C2 component contains no propylene basically, and can be directly sent to a downstream device to prepare ethylbenzene/styrene, and the propane or mixed C4 absorbent is from the inside of the system, and does not need to be introduced from the outside of the system, thus saving energy consumption.
(4) The invention realizes the high-efficiency recovery of components such as carbon dioxide, propylene and the like under the condition of shallow cooling, and the recovered carbon dioxide product is basically free of propylene; the recovered carbon dioxide product can be directly sent to downstream ethylbenzene/styrene production, so that the energy consumption of the downstream ethylbenzene/styrene production can be reduced, the benzene consumption can be reduced, and the quality of ethylbenzene and styrene products can be ensured. Meanwhile, dehydration and CO removal are not needed under the condition of shallow cooling2And the impurities and the refrigerant with lower temperature level are not needed, so that the investment and the consumption can be further reduced.
(5) The method further separates the recovered carbon three components into propylene and propane, the recovery rate of the propylene and the propane can also reach more than 99 wt%, the purity of the propylene product is not less than 99.6 v%, and the polymer-grade propylene can be obtained without further treatment.
(6) In the invention, the dry gas discharged from the top of the absorbent recovery tower mainly contains methane and hydrogen, and has less impurities, and the content of components of C2 and above C2 is not more than 2 vol%; the pressure of the dry gas is 2.1-2.7 MPaG, the purity can reach 40-70 mol%, and the hydrogen resource can be directly recovered by a pressure swing adsorption method.
(7) The invention can respectively desulfurize the gas phase and the liquid phase and remove mercaptan, and the gas phase is desulfurized under higher pressure, so the equipment volume is smaller, the investment is lower, and the desulfurization effect is good; meanwhile, the content of heavy hydrocarbon in the gas phase is reduced, the heavy hydrocarbon can be prevented from being condensed into the amine liquid, foam entrainment of a desulfurization device caused by the foaming of the amine liquid can be effectively avoided, and the stable operation of the device is ensured.
(8) In the invention, hydrogen sulfide and mercaptan are removed before entering the absorption tower and cannot be brought to a downstream light hydrocarbon recovery part, so that the problem of corrosion related to the light hydrocarbon recovery part caused by hydrogen sulfide is avoided, and meanwhile, the concentration of the downstream hydrogen sulfide is greatly reduced, thereby improving the safety; hydrogen sulfide and bisThe carbon oxide is separated in advance, so that the load and the energy consumption of a downstream light hydrocarbon recovery system can be reduced, and simultaneously, CO is generated2Is removed, and the quality of downstream products can be improved.
Additional features and advantages of the invention will be set forth in the detailed description which follows.
Drawings
The above and other objects, features and advantages of the present invention will become more apparent by describing in more detail exemplary embodiments thereof with reference to the attached drawings, in which like reference numerals generally represent like parts throughout.
FIG. 1 shows a process flow diagram for oil and gas recovery in example 1 of the present invention.
FIG. 2 shows a process flow diagram for oil and gas recovery in example 2 of the present invention.
FIG. 3 shows a process flow diagram for oil and gas recovery in example 3 of the present invention.
Description of reference numerals:
1. a gas-liquid separation tank I; 2. a compressor I; 3. a light and heavy gasoline separation tower; 4. a compressor II; 5. a light hydrocarbon-light gasoline separation tower; 6. a compressor III; 7. a cooler I; 8. a gas-liquid separation tank II; 9. a rich gas desulfurization tower; 10. a rich gas caustic wash tower; 11. a liquid hydrocarbon desulfurization tower; 12. a liquid hydrocarbon sweetening reactor; 13. a cooler II; 14. a feed tank; 15. an absorption tower; 16. a demethanizer; 17. a deethanizer; 18. an impurity processing unit; 19. a depropanizer; 20. a propylene rectification column; 21. an absorbent recovery column;
s-1, oil gas from an upstream device; s-2, crude gasoline; s-3, lean amine liquid; s-4, amine-rich liquid; s-5, alkali liquor; s-6, alkali liquor to be regenerated; s-7, a carbon four absorbent; s-8, dry gas; s-9, mixing a carbon dioxide product; s-10, propylene products; s-11, propane product; s-12, mixing the carbon four product; s-13, light gasoline products; s-14, heavy gasoline product.
Detailed Description
Preferred embodiments of the present invention will be described in more detail below. While the following describes preferred embodiments of the present invention, it should be understood that the present invention may be embodied in various forms and should not be limited by the embodiments set forth herein.
The properties of the feed oil and gas in the following examples are shown in table 1, and the properties of the C5+ component in the oil and gas are shown in table 2:
TABLE 1
TABLE 2
Example 1
The oil gas recovery device comprises:
the system comprises an oil gas feeding pipeline, a gas-liquid separation tank I1, a compressor I2, a light and heavy gasoline separation tower 3, a compressor II 4, a light hydrocarbon-light gasoline separation tower 5, a compressor III 6, a cooler I7, a gas-liquid separation tank II 8, a rich gas desulfurization tower 9, a rich gas alkaline washing tower 10, a liquid hydrocarbon desulfurization tower 11, a liquid hydrocarbon sweetening reactor 12, a cooler II 13, a feeding tank 14, an absorption tower 15, a demethanizer 16, a deethanizer 17, a depropanizer 19, a propylene rectification/20 and an absorbent recovery tower 21;
the oil-gas feeding pipeline is connected with an inlet of a gas-liquid separation tank I1, the top of the gas-liquid separation tank I1 is sequentially connected with a compressor I2 and a light and heavy gasoline separation tower 3, and the bottom of the tank is connected with a light and heavy gasoline separation tower 5;
the top of the light and heavy gasoline separation tower 3 is provided with a reflux tank I, the top of the reflux tank I is sequentially connected with a compressor II 4 and a light hydrocarbon-light gasoline separation tower 5, the bottom of the tank is connected with a booster pump and then connected with the light hydrocarbon-light gasoline separation tower 5, and the bottom of the light and heavy gasoline separation tower 3 is provided with a heavy gasoline extraction pipeline;
a reflux tank II is arranged at the top of the light hydrocarbon-light gasoline separation tower 5, the top of the reflux tank II is sequentially connected with a compressor III 6, a cooler I7 and a gas-liquid separation tank II 8, and the bottom of the reflux tank II is connected with a booster pump and then connected with the gas-liquid separation tank II 8;
the top of the gas-liquid separation tank II 8 is sequentially connected with a rich gas desulfurizing tower 9, a rich gas alkaline washing tower 10 and a cooler II 13, and the bottom of the tank is sequentially connected with a liquid hydrocarbon desulfurizing tower 11, a liquid hydrocarbon sweetening reactor 12 and the cooler II 13;
the upper part of the rich gas desulfurization tower 9 is provided with a lean amine liquid feeding pipeline, and the upper part of the rich gas caustic wash tower 10 is provided with an alkali liquid feeding pipeline;
the cooler II 13 is connected with the feeding tank 14;
the top of the feed tank 14 is connected with the absorption tower, and the bottom of the feed tank is connected with the demethanizer 16;
the top of the absorption tower 15 is connected with an absorbent recovery tower 21, the bottom of the absorption tower 15 is connected with a cooler II 13, and the upper part of the absorption tower 15 is provided with a mixed C4 absorbent feeding pipeline;
the top of the demethanizer 16 is connected with a cooler II 7, and the bottom of the demethanizer is connected with a deethanizer 17;
a mixed C2 produced pipeline is arranged at the top of the deethanizer 17, an impurity processing unit is arranged on the mixed C2 produced pipeline, the bottom of the deethanizer is connected with the depropanizer 19, and a propane absorbent feeding pipeline is arranged at the upper part of the deethanizer 17;
a mixed C3 produced pipeline is arranged at the upper part of the depropanizing tower 19, a mixed C3 produced pipeline is connected with the propylene rectifying tower 20, a mixed C4 product produced pipeline is arranged at the bottom of the depropanizing tower, the mixed C4 product produced pipeline is divided into two branches, and one branch is used as a mixed C4 absorbent feeding pipeline;
a propylene product extraction pipeline is arranged at the top of the propylene rectifying tower 20, a propane product extraction pipeline is arranged at the bottom of the propylene rectifying tower, the propane product extraction pipeline is divided into two branches, and one branch is used as a propane absorbent feeding pipeline;
the top of the absorbent recovery tower 21 is provided with a dry gas extraction pipeline, the bottom of the absorbent recovery tower 21 is connected with the light and heavy gasoline separation tower 3, the upper part of the absorbent recovery tower 21 is provided with a heavy gasoline absorbent feeding pipeline, the light and heavy gasoline separation tower 3 is divided into two heavy gasoline extraction pipelines, and one of the two heavy gasoline absorbent feeding pipelines is used as a heavy gasoline absorbent feeding pipeline.
The oil gas recovery is carried out by adopting the device, and the recovery flow is shown in figure 1:
(1) first gas-liquid separation: oil gas from an upstream device is condensed and cooled and then sent to a gas-liquid separation tank I1 for gas-liquid separation, a liquid phase at the bottom of the tank is pressurized and sent to a light and heavy gasoline cutting tower 3, and a gas phase at the top of the tank is pressurized by a compressor and then sent to the light and heavy gasoline cutting tower 3;
(2) separating light gasoline and heavy gasoline: the material from the gas-liquid separation tank I1 enters a light and heavy gasoline separation tower 3, the gas phase distilled from the tower top is condensed and enters a tower top reflux tank, the gas phase at the top of the tower top reflux tank is compressed and then sent to a light hydrocarbon-light gasoline separation tower 5, the liquid phase at the bottom of the tank is pressurized and then sent to the light hydrocarbon-light gasoline separation tower 5, and at least part of the liquid phase at the bottom of the light and heavy gasoline separation tower 3 is extracted as a heavy gasoline product S-14; wherein the operation temperature of the top of the light and heavy gasoline separating tower 3 is 60-85 ℃, the operation temperature of the bottom of the tower is 140-190 ℃, the operation pressure is 0.25-0.5 MPaG, and the initial boiling point of the heavy gasoline is 60-85 ℃.
(3) Light hydrocarbon-light gasoline separation: the material flow from the top reflux tank of the light and heavy gasoline separation tower 3 enters a light hydrocarbon-light gasoline separation tower 5, the gas phase distilled from the top of the tower enters a top reflux tank, the gas phase at the top of the top reflux tank is compressed and cooled and then sent to a gas-liquid separation tank II 8, the liquid phase at the bottom of the tank is pressurized and then sent to the gas-liquid separation tank II 8, and the liquid phase at the bottom of the tank is taken as a light gasoline product S-13 to be extracted; wherein the operating temperature of the light hydrocarbon-light gasoline separating tower 5 is 55-80 ℃, the operating pressure is 1.0-1.35 MPaG, and the dry point of the light gasoline is 65-90 ℃;
(4) second gas-liquid separation: after the materials are mixed and gas-liquid balanced in the gas-liquid separation tank II 8, the gas phase and the liquid phase are separated again, and then impurities are respectively removed; wherein the operating temperature of the gas-liquid separation tank II 8 is 35-45 ℃, and the operating pressure is 2.3-2.9 MPaG;
(5) gas-phase impurity removal: the gas phase on the top of the gas-liquid separation tank II 8 is sequentially subjected to H removal in a rich gas desulfurization tower 9 by taking lean amine liquid S-3 as an absorbent2S and CO2In the rich gas alkaline washing tower 10, mercaptan is removed by taking alkali liquor S-5 as an absorbent, and then the gas is sent to a cooler; wherein the operation temperature of the rich gas desulfurization tower 9 isThe operation pressure is 2.2-2.8 MPaG at the temperature of 35-45 ℃; the operation temperature of the rich gas alkaline washing tower 10 is 35-45 ℃, and the operation pressure is 2.2-2.8 MPaG;
(6) liquid phase impurity removal: the liquid phase at the bottom of the tank separated by the gas-liquid separation tank II 8 is sequentially subjected to H removal in a liquid hydrocarbon desulfurization tower 112S and CO2After mercaptan is removed in the liquid hydrocarbon mercaptan removal reactor 12, the liquid hydrocarbon mercaptan removed is sent to a cooler; wherein the operation temperature of the liquid hydrocarbon desulfurizing tower 11 is 35-45 ℃, and the operation pressure is 3.0-3.5 MPaG;
(7) and (3) cooling: the gaseous light hydrocarbon and the liquid light hydrocarbon after impurity removal are mixed and cooled in a cooler and then are sent to a feeding tank 14;
(8) feeding: after the mixture flow from the cooler is mixed, pre-absorbed and gas-liquid balanced in the feeding tank 14, the gas phase at the top of the tank is sent to the absorption tower 15, and the liquid phase at the bottom of the tank is sent to the demethanizer 16; wherein the operating temperature of the feeding tank 14 is 5-25 ℃, and the operating pressure is 2.2-2.8 MPaG
(9) Absorption: in the absorption tower 15, the mixed C4 is used as an absorbent to absorb components with the content of C2 and above C2 in the gas phase from the top of the feed tank 14, and simultaneously, part of methane is absorbed, the gas phase at the top of the absorption tower 15 is sent to an absorbent recovery tower 21, and the liquid phase at the bottom of the absorption tower is returned to a cooler; wherein the operation temperature of the absorption tower 15 is 5-25 ℃, and the operation pressure is 2.1-2.7 MPaG;
(10) separation:
demethanization: the liquid phase from the bottom of the feed tank 14 removes methane in the demethanizer 16, and simultaneously removes a small part of components with the carbon number of 2 and more than 2, the gas phase at the top of the demethanizer 16 is sent to a cooler, and the liquid phase at the bottom of the demethanizer is sent to a deethanizer 17;
deethanizing: separating C2 components from a liquid phase at the bottom of the demethanizer 16 in a deethanizer 17 by taking a propane product S-11 as an absorbent, treating impurities of a mixed C2 component at the top of the separated tower, and then extracting the mixed C2 component as a mixed C2 product S-9, and distributing liquid phase components of C3 and more than C3 at the bottom of the tower to a depropanizer 19; wherein the operation temperature at the top of the deethanizer is 15-30 ℃, and the operation pressure is 2.6-3.2 MPaG;
depropanizing: the liquid phase component from the bottom of the deethanizer 17 is further separated in the depropanizer 19, the separated C3 component is sent to the propylene rectifying tower 20, at least one part of the bottom component is sent to the absorption tower as the mixed C4 absorbent, and the rest is extracted as the mixed C4 product S-12;
and (3) propylene rectification: c3 components from the upper part of the depropanizing tower 19 are further rectified in a propylene rectifying tower 20, the gas phase at the top of the propylene rectifying tower 20 is cooled and then extracted as a propylene product S-10, at least one part of the liquid phase at the bottom of the tower is extracted as a propane product S-11, and the rest part of the liquid phase is heated and then sent to the deethanizing tower 17 as a propane absorbent S-15; wherein the operating temperature of the propylene rectifying tower is 45-60 ℃, and the operating pressure is 1.8-2.0 MPaG;
(11) and (3) recovering the absorbent: in the absorbent recovery tower 21, a part of heavy gasoline products S-14 extracted in the step (2) is taken as an absorbent to absorb components of C4 and above C4 in a gas phase from the top of the absorption tower 15, and simultaneously absorb a small amount of components of C2/C3, the gas phase at the top of the absorbent recovery tower 21 is extracted as dry gas S-8, and a liquid phase at the bottom of the absorbent recovery tower is returned to the light and heavy gasoline separation tower 3; wherein the operating pressure of the absorbent recovery tower is 2.1-2.7 MPaG at 15-40 ℃.
The propane absorbent S-15 extracted from the bottom of the propylene rectification column and sent back to the deethanizer 17 was 6500kg/h, and the composition and flow rate of each recovered product are as shown in tables 3 and 4:
TABLE 3
TABLE 4
Example 2
The oil gas recovery process flow shown in fig. 2 is different from the process flow of example 1 in that: in this example, the deethanizer 17 uses a portion of the mixed C4 fraction S-15 taken from the bottom of the depropanizer 19 as an absorbent to separate the C2 fraction.
Wherein, the mixed carbon four absorbent S-12 extracted from the bottom of the depropanizer 19 and sent back to the deethanizer 17 is 5000kg/h, and the composition, flow and property of each recovered product are shown in tables 5 and 6:
TABLE 5
TABLE 6
Example 3
The oil gas is recovered by adopting the process flow shown in figure 3, which is different from the process flow in the embodiment 1 in that: in this embodiment, the light hydrocarbon separation is sequentially performed by demethanization, depropanization, and deethanization, wherein the top of the deethanizer 17 uses a portion of propane collected from the bottom of the propylene rectification column 20 as the absorbent S-11 to separate the C2 component.
Wherein, the propane absorbent S-11 extracted from the bottom of the propylene rectifying tower 20 and returned to the deethanizer 17 is 6500kg/h, and the composition, flow and property of each recovered product are shown in tables 7 and 8:
TABLE 7
TABLE 8
The data in the table show that the process is simple, the operation condition is mild, the cold consumption is low, the separation and recovery of light gasoline and light hydrocarbon in oil gas can be realized by using less equipment, particularly the high-efficiency recovery of components such as carbon dioxide and propylene can be realized under the condition of shallow cooling, and the recovered carbon dioxide product is basically free of propylene; and secondary separation process does not exist between the carbon two and each component, and meanwhile, the total recovery rate of the carbon two can be ensured to be more than 98 wt%, the recovery rate of the propylene component can be more than 99 wt%, the content of methane in the recovered carbon two is not more than 1 vol%, and the content of ethane in the recovered carbon three is not more than 200 ppmv; the recovered dry gas contains less impurities, the content of components of C2 and above C2 is not more than 2 vol%, and the purity of the hydrogen can reach above 40 mol%.
Having described embodiments of the present invention, the foregoing description is intended to be exemplary, not exhaustive, and not limited to the embodiments disclosed. Many modifications and variations will be apparent to those of ordinary skill in the art without departing from the scope and spirit of the described embodiments.
Claims (10)
1. A method of oil and gas recovery, the method comprising:
(1) first gas-liquid separation: oil gas from an upstream device is condensed and cooled and then sent to a gas-liquid separation tank I for gas-liquid separation, a liquid phase at the bottom of the tank is pressurized and sent to a light and heavy gasoline cutting tower, and a gas phase at the top of the tank is pressurized by a compressor and then sent to the light and heavy gasoline cutting tower;
(2) separating light gasoline and heavy gasoline: the material from the gas-liquid separation tank I enters a light and heavy gasoline separation tower, the gas phase distilled from the tower top is condensed and enters a tower top reflux tank, the gas phase at the top of the tower top reflux tank is compressed and then sent to a light hydrocarbon-light gasoline separation tower, the liquid phase at the bottom of the tank is pressurized and then sent to the light hydrocarbon-light gasoline separation tower, and at least part of the liquid phase at the bottom of the light and heavy gasoline separation tower is extracted as a heavy gasoline product;
(3) light hydrocarbon-light gasoline separation: the material flow from the top reflux tank of the light and heavy gasoline separation tower enters a light hydrocarbon-light gasoline separation tower, the gas phase distilled from the top of the tower enters a top reflux tank, the gas phase at the top of the top reflux tank is compressed and cooled and then sent to a gas-liquid separation tank II, the liquid phase at the bottom of the tank is pressurized and then sent to the gas-liquid separation tank II, and the liquid phase at the bottom of the tank is extracted as light gasoline;
(4) second gas-liquid separation: after the materials are mixed and gas-liquid balanced in the gas-liquid separation tank II, the gas phase and the liquid phase are separated again, and then impurities are respectively removed;
(5) gas-phase impurity removal: the gas phase on the top of the gas-liquid separation tank II is sequentially subjected to H removal in a rich gas desulfurization tower by taking lean amine liquid as an absorbent2S and CO2Removing mercaptan in a rich gas alkaline tower by taking alkali liquor as an absorbent, and then sending the rich gas alkaline tower to a cooler;
(6) liquid phase impurity removal: the liquid phase at the bottom of the tank separated by the gas-liquid separation tank II is sequentially subjected to H removal in a liquid hydrocarbon desulfurization tower2S and CO2After mercaptan is removed in the liquid hydrocarbon mercaptan removal reactor, the liquid hydrocarbon mercaptan removal reactor is sent to a cooler;
(7) and (3) cooling: mixing and cooling the gaseous light hydrocarbon and the liquid light hydrocarbon which are subjected to impurity removal in a cooler, and then sending the mixture to a feeding tank;
(8) feeding: after the mixture flow from the cooler is mixed, pre-absorbed and gas-liquid balanced in a feeding tank, the gas phase at the top of the tank is sent to an absorption tower, and the liquid phase at the bottom of the tank is sent to a separation unit;
(9) absorption: in the absorption tower, the mixed C4 is used as an absorbent to absorb components with the content of C2 and above C2 in a gas phase from the top of a feed tank, and simultaneously, part of methane is absorbed, the gas phase at the top of the absorption tower is sent to a downstream device, and a liquid phase at the bottom of the absorption tower is returned to a cooler;
(10) separation: the liquid phase from the bottom of the feed tank is further separated into C2, C3 and C4 components through a demethanizer, a deethanizer, a depropanizer and an optional propylene rectifying tower in a separation unit, wherein, propane and/or mixed C4 in the deethanizer is used as absorbent to separate C2 components, C2 and C3 components are respectively extracted as C2 and C3 products, at least one part of C4 components is sent to the absorption tower and the optional deethanizer as mixed C4 absorbent, and the rest is extracted as mixed C4 product.
2. The method according to claim 1, wherein the separating in step (10) comprises one of the following three ways:
in a first mode, the separating step sequentially includes:
demethanization: removing methane from the liquid phase at the bottom of the feed tank in a demethanizer, simultaneously removing a small part of components with the content of C2 and above C2, sending the gas phase at the top of the demethanizer to a cooler, and sending the liquid phase at the bottom of the demethanizer to a deethanizer;
deethanizing: separating C2 component from liquid phase at the bottom of the demethanizer in a deethanizer by taking propane as an absorbent, optionally treating impurities of the separated mixed C2 component at the top of the deethanizer, and then extracting the mixed C2 component as a mixed C2 product, and distributing the liquid phase components at the bottom of the deethanizer, which are more than C3 and C3 to the depropanizer;
depropanizing: further separating liquid phase components from the bottom of the deethanizer in the depropanizer, extracting separated C3 components from the upper part of the depropanizer, sending at least one part of the bottom components to an absorption tower as a mixed C4 absorbent, and extracting the rest as a mixed C4 product;
preferably, the separating further comprises:
and (3) propylene rectification: c3 components from the upper part of the depropanizing tower are further rectified in a propylene rectifying tower, the gas phase at the top of the propylene rectifying tower is taken out as a propylene product after being cooled, at least one part of the liquid phase at the bottom of the propylene rectifying tower is taken out as a propane product, and the rest part of the liquid phase is taken as a propane absorbent after being heated and then sent to the deethanizing tower;
in a second mode, the separating step sequentially comprises:
demethanization: removing methane from the liquid phase at the bottom of the feed tank in a demethanizer, simultaneously removing a small part of components with the content of C2 and above C2, sending the gas phase at the top of the demethanizer to a cooler, and sending the liquid phase at the bottom of the demethanizer to a deethanizer;
deethanizing: separating C2 components from a liquid phase at the bottom of the demethanizer in a deethanizer by taking mixed C4 as an absorbent, optionally treating impurities of the separated mixed C2 components at the top of the deethanizer, extracting the treated components as a mixed C2 product, and distributing liquid phase components above C3 and C3 at the bottom of the deethanizer;
depropanizing: further separating liquid phase components from the bottom of the deethanizer in the depropanizer, extracting separated C3 components from the upper part of the depropanizer, at least one part of the tower bottom components serving as a mixed C4 absorbent is respectively sent to an absorption tower and the deethanizer, and the rest part serving as a mixed C4 product is extracted;
preferably, the separating further comprises:
and (3) propylene rectification: c3 component from the upper part of the depropanizing tower is further rectified in a propylene rectifying tower, the gas phase at the top of the propylene rectifying tower is taken out as a propylene product after being cooled, and the liquid phase at the bottom of the propylene rectifying tower is taken out as a propane product;
in a third mode, the separating step sequentially comprises:
demethanization: removing methane from the liquid phase at the bottom of the feed tank in a demethanizer, simultaneously removing a small part of components with the carbon number of C2 and more than C2, sending the gas phase at the top of the demethanizer to a cooler, and sending the liquid phase at the bottom of the demethanizer to a depropanizer;
depropanizing: separating liquid phase components from the bottom of the demethanizer in a depropanizer, extracting components with the C3 and the C3 or less from the upper part of the depropanizer, optionally drying, and then sending to the depropanizer, wherein at least one part of the tower bottom components is taken as a mixed C4 absorbent and sent to an absorption tower, and the rest is taken as a mixed C4 product;
deethanizing: the gas phase from the upper part of the depropanizing tower is further separated in the deethanizing tower by taking propane as an absorbent, the separated mixed C2 component at the top of the tower is extracted as a mixed C2 product after being optionally subjected to impurity treatment, and the liquid phase at the bottom of the tower is extracted as a mixed C3 component;
preferably, the separating further comprises:
and (3) propylene rectification: the mixed C3 component from the bottom of the deethanizer is further rectified in a propylene rectifying tower, the gas phase at the top of the propylene rectifying tower is cooled and then extracted as a propylene product, at least one part of the liquid phase at the bottom of the tower is extracted as a propane product, and the rest part of the liquid phase is sent to the deethanizer as a propane absorbent.
3. The method of claim 1, further comprising:
(11) and (3) recovering the absorbent: in the absorbent recovery tower, part of the heavy gasoline product extracted in the step (2) is used as an absorbent to absorb components of C4 and above C4 in the gas phase from the top of the absorption tower, and simultaneously absorb a small amount of components of C2/C3, the gas phase at the top of the absorbent recovery tower is extracted as dry gas, and the liquid phase at the bottom of the absorbent recovery tower is returned to the light and heavy gasoline separation tower.
4. The method of claim 1,
the operation temperature of the top of the light and heavy gasoline separation tower is 60-85 ℃, the operation temperature of the bottom of the light and heavy gasoline separation tower is 140-190 ℃, and the operation pressure is 0.25-0.5 MPaG;
the operating temperature of the light hydrocarbon-light gasoline separating tower is 55-80 ℃, and the operating pressure is 1.0-1.35 MPaG;
the initial boiling point of the heavy gasoline is 60-85 ℃, and the dry point of the light gasoline is 65-90 ℃;
the operating temperature of the gas-liquid separation tank II is 35-45 ℃, and the operating pressure is 2.3-2.9 MPaG;
the operation temperature of the rich gas desulfurization tower is 35-45 ℃, and the operation pressure is 2.2-2.8 MPaG;
the operation temperature of the rich gas alkaline washing tower is 35-45 ℃, and the operation pressure is 2.2-2.8 MPaG;
the operating temperature of the liquid hydrocarbon desulfurization tower is 35-45 ℃, and the operating pressure is 3.0-3.5 MPaG;
the operating temperature of the feeding tank is 5-25 ℃, and the operating pressure is 2.2-2.8 MPaG;
the operation temperature of the absorption tower is 5-25 ℃, the operation pressure is 2.1-2.7 MPaG, and the absorbent in the absorption tower is a self-balancing mixed C4 component in the system and does not need to be introduced from the outside of the system.
5. The method of claim 2,
the operation temperature at the top of the deethanizer is 15-30 ℃, and the operation pressure is 2.6-3.2 MPaG; the propane absorbent and/or the mixed C4 absorbent come from propane and/or mixed C4 components from self-balancing in the system and do not need to be introduced from the outside of the system;
the operating temperature of the propylene rectifying tower is 45-60 ℃, and the operating pressure is 1.8-2.0 MPaG.
6. The method of claim 3,
the operating pressure of the absorbent recovery tower is 2.1-2.7 MPaG at 15-40 ℃.
7. An oil and gas recovery device, characterized in that the device comprises: the system comprises an oil-gas feeding pipeline, a gas-liquid separation tank I, a compressor I, a light and heavy gasoline separation tower, a compressor II, a light hydrocarbon-light gasoline separation tower, a compressor III, a cooler I, a gas-liquid separation tank II, a rich gas desulfurization tower, a rich gas alkaline washing tower, a liquid hydrocarbon desulfurization tower, a liquid hydrocarbon sweetening reactor, a cooler II, a feeding tank, an absorption tower and a separation unit;
the oil-gas feeding pipeline is connected with an inlet of a gas-liquid separation tank I, the top of the gas-liquid separation tank I is sequentially connected with a compressor I and a light-heavy gasoline separation tower, and the bottom of the gas-liquid separation tank I is connected with the light-heavy gasoline separation tower;
the top of the light and heavy gasoline separation tower is provided with a reflux tank I, the top of the reflux tank I is sequentially connected with a compressor II and a light hydrocarbon-light gasoline separation tower, the bottom of the tank is connected with a booster pump and then connected with the light hydrocarbon-light gasoline separation tower, and the bottom of the light and heavy gasoline separation tower is provided with a heavy gasoline extraction pipeline;
a reflux tank II is arranged at the top of the light hydrocarbon-light gasoline separation tower, the top of the reflux tank II is sequentially connected with a compressor III, a cooler I and a gas-liquid separation tank II, and the bottom of the reflux tank II is connected with a booster pump and then connected with the gas-liquid separation tank II;
the top of the gas-liquid separation tank II is sequentially connected with a rich gas desulfurization tower, a rich gas alkaline washing tower and a cooler II, and the bottom of the tank is sequentially connected with a liquid hydrocarbon desulfurization tower, a liquid hydrocarbon sweetening reactor and the cooler II;
the upper part of the rich gas desulfurization tower is provided with a lean amine liquid feeding pipeline, and the upper part of the rich gas caustic tower is provided with an alkali liquid feeding pipeline;
the cooler II is connected with the feeding tank;
the top of the feeding tank is connected with the absorption tower, and the bottom of the tank is connected with the separation unit;
the top of the absorption tower is connected with a downstream device, the bottom of the absorption tower is connected with a cooler II, and the upper part of the absorption tower is provided with a mixed C4 absorbent feeding pipeline;
the separation unit includes: a demethanizer, deethanizer, depropanizer, and optionally a propylene rectification column; the top of the demethanizer is connected with a cooler II; a mixed C2 produced pipeline is arranged at the top of the deethanizer, an impurity treatment unit is optionally arranged on the mixed C2 produced pipeline, and a propane or mixed C4 absorbent feeding pipeline is arranged at the upper part of the deethanizer; the bottom of the depropanizing tower is provided with a mixed C4 product extraction pipeline, the mixed C4 product extraction pipeline is divided into two branches, and one branch is used as a mixed C4 absorbent feeding pipeline.
8. The apparatus of claim 7,
the top of the demethanizer is connected with a cooler II, and the bottom of the demethanizer is connected with a deethanizer;
a mixed C2 extraction pipeline is arranged at the top of the deethanizer, an impurity treatment unit is optionally arranged on the mixed C2 extraction pipeline, the bottom of the deethanizer is connected with the depropanizer, and a propane absorbent feeding pipeline is arranged at the upper part of the deethanizer;
the upper part of the depropanizing tower is provided with a mixed C3 produced pipeline, the mixed C3 produced pipeline is optionally connected with the propylene rectifying tower, the bottom of the depropanizing tower is provided with a mixed C4 product produced pipeline, the mixed C4 product produced pipeline is divided into two branches, and one branch is used as a mixed C4 absorbent feeding pipeline;
preferably, a propylene product extraction pipeline is arranged at the top of the propylene rectifying tower, a propane product extraction pipeline is arranged at the bottom of the propylene rectifying tower, the propane product extraction pipeline is divided into two branches, and one branch is used as a propane absorbent feeding pipeline;
or,
the top of the demethanizer is connected with a cooler II, and the bottom of the demethanizer is connected with a deethanizer;
a mixed C2 produced pipeline is arranged at the top of the deethanizer, an impurity treatment unit is optionally arranged on the mixed C2 produced pipeline, the bottom of the deethanizer is connected with the depropanizer, and a mixed C4 absorbent feeding pipeline is arranged at the upper part of the deethanizer;
a mixed C3 produced pipeline is arranged at the upper part of the depropanizing tower, the mixed C3 produced pipeline is optionally connected with the propylene rectifying tower, a mixed C4 product produced pipeline is arranged at the bottom of the depropanizing tower, the mixed C4 product produced pipeline is divided into two branches, one branch is used as a mixed C4 absorbent feeding pipeline and is respectively connected with the absorption tower and the deethanizing tower;
preferably, a propylene product extraction pipeline is arranged at the top of the propylene rectifying tower, and a propane product extraction pipeline is arranged at the bottom of the propylene rectifying tower;
or,
the top of the demethanizer is connected with a cooler II, and the bottom of the demethanizer is connected with a depropanizer;
the upper part of the depropanizing tower is connected with a drying unit optionally and then connected with a deethanizing tower, a mixed C4 product extraction pipeline is arranged at the bottom of the depropanizing tower, the mixed C4 product extraction pipeline is divided into two branches, and one branch is used as a mixed C4 absorbent feeding pipeline;
a mixed C2 produced pipeline is arranged at the top of the deethanizer, an impurity treatment unit is optionally arranged on the mixed C2 produced pipeline, a mixed C3 produced pipeline is arranged at the bottom of the deethanizer, the mixed C3 produced pipeline is optionally connected with a propylene rectifying tower, and a propane absorbent feeding pipeline is arranged at the upper part of the deethanizer;
preferably, a propylene product extraction pipeline is arranged at the top of the propylene rectifying tower, a propane product extraction pipeline is arranged at the bottom of the propylene rectifying tower, the propane product extraction pipeline is divided into two branches, and one branch is used as a propane absorbent feeding pipeline.
9. The apparatus of claim 7, wherein the downstream apparatus further comprises an absorbent recovery column;
the top of the absorbent recovery tower is provided with a dry gas extraction pipeline, the bottom of the absorbent recovery tower is connected with a light and heavy gasoline separation tower, the upper part of the absorbent recovery tower is provided with a heavy gasoline absorbent feeding pipeline, the heavy gasoline extraction pipeline of the light and heavy gasoline separation tower is divided into two branches, and one branch is used as the heavy gasoline absorbent feeding pipeline.
10. The apparatus of claim 7,
the absorption tower is provided with 2-5 middle-section refluxes;
the top of the demethanizer is not provided with a condenser, and the bottom of the demethanizer is provided with a reboiler;
the apparatus does not include a dehydration apparatus.
Priority Applications (8)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201910740666.3A CN111394116B (en) | 2019-08-12 | 2019-08-12 | Oil gas recovery method and device |
| PCT/CN2020/094728 WO2020244639A1 (en) | 2019-06-06 | 2020-06-05 | Oil and gas processing method and device |
| US17/281,980 US11946002B2 (en) | 2019-06-06 | 2020-06-05 | Method and device for treating oil gas |
| EP20818004.2A EP3981860A4 (en) | 2019-06-06 | 2020-06-05 | Oil and gas processing method and device |
| BR112021005521-5A BR112021005521A2 (en) | 2019-06-06 | 2020-06-05 | method and device for treatment of petroleum gas |
| JP2021518784A JP7558933B2 (en) | 2019-06-06 | 2020-06-05 | Oil and gas processing method and device |
| SA521421653A SA521421653B1 (en) | 2019-06-06 | 2021-04-04 | Method and device for treating oil gas |
| US18/437,252 US20240182799A1 (en) | 2019-06-06 | 2024-02-09 | Method and device for treating oil gas |
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