CN112831349A - Method for improving utilization efficiency of associated gas of oil field operation station - Google Patents
Method for improving utilization efficiency of associated gas of oil field operation station Download PDFInfo
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- 238000000034 method Methods 0.000 title claims abstract description 43
- 239000007789 gas Substances 0.000 claims abstract description 122
- 238000010521 absorption reaction Methods 0.000 claims abstract description 62
- 230000002745 absorbent Effects 0.000 claims abstract description 54
- 239000002250 absorbent Substances 0.000 claims abstract description 54
- 238000010438 heat treatment Methods 0.000 claims abstract description 24
- 238000000746 purification Methods 0.000 claims abstract description 19
- 239000002737 fuel gas Substances 0.000 claims abstract description 12
- 239000002274 desiccant Substances 0.000 claims abstract description 11
- 150000001412 amines Chemical class 0.000 claims description 39
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims description 24
- 239000007788 liquid Substances 0.000 claims description 19
- GLUUGHFHXGJENI-UHFFFAOYSA-N Piperazine Chemical compound C1CNCCN1 GLUUGHFHXGJENI-UHFFFAOYSA-N 0.000 claims description 18
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Chemical group O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 14
- ZLMJMSJWJFRBEC-UHFFFAOYSA-N Potassium Chemical group [K] ZLMJMSJWJFRBEC-UHFFFAOYSA-N 0.000 claims description 13
- 229910021536 Zeolite Inorganic materials 0.000 claims description 13
- HNPSIPDUKPIQMN-UHFFFAOYSA-N dioxosilane;oxo(oxoalumanyloxy)alumane Chemical compound O=[Si]=O.O=[Al]O[Al]=O HNPSIPDUKPIQMN-UHFFFAOYSA-N 0.000 claims description 13
- 239000002808 molecular sieve Substances 0.000 claims description 13
- 239000011591 potassium Substances 0.000 claims description 13
- 229910052700 potassium Inorganic materials 0.000 claims description 13
- URGAHOPLAPQHLN-UHFFFAOYSA-N sodium aluminosilicate Chemical compound [Na+].[Al+3].[O-][Si]([O-])=O.[O-][Si]([O-])=O URGAHOPLAPQHLN-UHFFFAOYSA-N 0.000 claims description 13
- 239000002904 solvent Substances 0.000 claims description 13
- 239000010457 zeolite Substances 0.000 claims description 13
- 239000001569 carbon dioxide Substances 0.000 claims description 12
- 229910002092 carbon dioxide Inorganic materials 0.000 claims description 12
- VILCJCGEZXAXTO-UHFFFAOYSA-N 2,2,2-tetramine Chemical compound NCCNCCNCCN VILCJCGEZXAXTO-UHFFFAOYSA-N 0.000 claims description 8
- 238000011069 regeneration method Methods 0.000 claims description 8
- 238000012360 testing method Methods 0.000 claims description 8
- 229960001124 trientine Drugs 0.000 claims description 8
- 239000008367 deionised water Substances 0.000 claims description 7
- 229910021641 deionized water Inorganic materials 0.000 claims description 7
- CRVGTESFCCXCTH-UHFFFAOYSA-N methyl diethanolamine Chemical compound OCCN(C)CCO CRVGTESFCCXCTH-UHFFFAOYSA-N 0.000 claims description 7
- 230000008929 regeneration Effects 0.000 claims description 7
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 claims description 6
- 229910000037 hydrogen sulfide Inorganic materials 0.000 claims description 6
- 238000002156 mixing Methods 0.000 claims description 6
- 238000004064 recycling Methods 0.000 claims description 5
- 239000011148 porous material Substances 0.000 claims description 4
- 239000002994 raw material Substances 0.000 claims description 4
- 230000003009 desulfurizing effect Effects 0.000 claims description 3
- 238000002485 combustion reaction Methods 0.000 abstract description 15
- RAHZWNYVWXNFOC-UHFFFAOYSA-N Sulphur dioxide Chemical compound O=S=O RAHZWNYVWXNFOC-UHFFFAOYSA-N 0.000 abstract description 12
- 239000010815 organic waste Substances 0.000 abstract description 6
- 239000003921 oil Substances 0.000 description 9
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 8
- 230000018044 dehydration Effects 0.000 description 4
- 238000006297 dehydration reaction Methods 0.000 description 4
- 239000003345 natural gas Substances 0.000 description 4
- 238000005262 decarbonization Methods 0.000 description 3
- 238000006477 desulfuration reaction Methods 0.000 description 3
- 230000023556 desulfurization Effects 0.000 description 3
- 150000002430 hydrocarbons Chemical class 0.000 description 3
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 2
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 2
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 description 2
- 238000009825 accumulation Methods 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 2
- 229910052799 carbon Inorganic materials 0.000 description 2
- 230000007797 corrosion Effects 0.000 description 2
- 238000005260 corrosion Methods 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 238000002474 experimental method Methods 0.000 description 2
- 239000000446 fuel Substances 0.000 description 2
- 229930195733 hydrocarbon Natural products 0.000 description 2
- 230000002035 prolonged effect Effects 0.000 description 2
- 239000011593 sulfur Substances 0.000 description 2
- 229910052717 sulfur Inorganic materials 0.000 description 2
- 230000009466 transformation Effects 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
- CSDREXVUYHZDNP-UHFFFAOYSA-N alumanylidynesilicon Chemical compound [Al].[Si] CSDREXVUYHZDNP-UHFFFAOYSA-N 0.000 description 1
- XAGFODPZIPBFFR-UHFFFAOYSA-N aluminium Chemical compound [Al] XAGFODPZIPBFFR-UHFFFAOYSA-N 0.000 description 1
- 229910052782 aluminium Inorganic materials 0.000 description 1
- PNEYBMLMFCGWSK-UHFFFAOYSA-N aluminium oxide Inorganic materials [O-2].[O-2].[O-2].[Al+3].[Al+3] PNEYBMLMFCGWSK-UHFFFAOYSA-N 0.000 description 1
- 239000009096 changqing Substances 0.000 description 1
- 229910052681 coesite Inorganic materials 0.000 description 1
- 229910052593 corundum Inorganic materials 0.000 description 1
- 229910052906 cristobalite Inorganic materials 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000018109 developmental process Effects 0.000 description 1
- 238000001035 drying Methods 0.000 description 1
- 238000005485 electric heating Methods 0.000 description 1
- 239000012535 impurity Substances 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- -1 moisture Chemical class 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 239000005416 organic matter Substances 0.000 description 1
- 239000003209 petroleum derivative Substances 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 238000007670 refining Methods 0.000 description 1
- 229910052710 silicon Inorganic materials 0.000 description 1
- 239000010703 silicon Substances 0.000 description 1
- 239000000377 silicon dioxide Substances 0.000 description 1
- 235000012239 silicon dioxide Nutrition 0.000 description 1
- 229910052682 stishovite Inorganic materials 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 230000001360 synchronised effect Effects 0.000 description 1
- AGGKEGLBGGJEBZ-UHFFFAOYSA-N tetramethylenedisulfotetramine Chemical compound C1N(S2(=O)=O)CN3S(=O)(=O)N1CN2C3 AGGKEGLBGGJEBZ-UHFFFAOYSA-N 0.000 description 1
- 229910052905 tridymite Inorganic materials 0.000 description 1
- 239000002912 waste gas Substances 0.000 description 1
- 229910001845 yogo sapphire Inorganic materials 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G70/00—Working-up undefined normally gaseous mixtures obtained by processes covered by groups C10G9/00, C10G11/00, C10G15/00, C10G47/00, C10G51/00
- C10G70/04—Working-up undefined normally gaseous mixtures obtained by processes covered by groups C10G9/00, C10G11/00, C10G15/00, C10G47/00, C10G51/00 by physical processes
-
- 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
- C10G70/00—Working-up undefined normally gaseous mixtures obtained by processes covered by groups C10G9/00, C10G11/00, C10G15/00, C10G47/00, C10G51/00
- C10G70/04—Working-up undefined normally gaseous mixtures obtained by processes covered by groups C10G9/00, C10G11/00, C10G15/00, C10G47/00, C10G51/00 by physical processes
- C10G70/046—Working-up undefined normally gaseous mixtures obtained by processes covered by groups C10G9/00, C10G11/00, C10G15/00, C10G47/00, C10G51/00 by physical processes by adsorption, i.e. with the use of solids
- C10G70/047—Working-up undefined normally gaseous mixtures obtained by processes covered by groups C10G9/00, C10G11/00, C10G15/00, C10G47/00, C10G51/00 by physical processes by adsorption, i.e. with the use of solids by molecular sieve technique
-
- 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
- C10G70/00—Working-up undefined normally gaseous mixtures obtained by processes covered by groups C10G9/00, C10G11/00, C10G15/00, C10G47/00, C10G51/00
- C10G70/04—Working-up undefined normally gaseous mixtures obtained by processes covered by groups C10G9/00, C10G11/00, C10G15/00, C10G47/00, C10G51/00 by physical processes
- C10G70/06—Working-up undefined normally gaseous mixtures obtained by processes covered by groups C10G9/00, C10G11/00, C10G15/00, C10G47/00, C10G51/00 by physical processes by gas-liquid contact
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)
- Gas Separation By Absorption (AREA)
- Treating Waste Gases (AREA)
Abstract
The invention provides a method for improving the utilization efficiency of associated gas of an oil field operation station, which comprises the following specific steps: adding a gas absorption device and a dryer at the front end of an inlet of associated gas entering a heating furnace, wherein an absorbent is filled in the gas absorption device, and a drying agent is filled in the dryer; the gas separated by the three-phase separator of the station depends on the system pressure of the separator, firstly, the gas is desulfurized and decarbonized for the first-stage purification by the absorbent in the gas absorption device at normal temperature, and then, the gas is dehydrated for the second-stage purification by the dryer at normal temperature and then enters the heating furnace to be used as fuel gas. The invention improves the combustion efficiency of associated gas, reduces the discharge amount of organic waste gas and sulfur dioxide, and simultaneously prolongs the service life of pipelines and combustion furnaces of operation stations.
Description
Technical Field
The invention is applied to the field of recycling and reusing process gas of operation stations in the petroleum and natural gas development and refining industry, and particularly designs a method for improving the utilization efficiency of associated gas of an oil field operation station.
Background
A large amount of associated gas can be generated in the oil exploitation process, and at present, the associated gas in an oil well field is partially conveyed to be recycled mainly through technologies such as a wellhead constant pressure valve, a gas collecting pipeline laying, a compressor mixed conveying, a synchronous rotation oil-gas mixed conveying and the like; and if the associated gas is far away from the associated gas recovery station or the ground gas collection conveying pipe network is incomplete, the associated gas is conveyed to operation stations such as a booster station, a combined station and the like to be directly used as the fuel of the heating furnace. However, the operation stations such as the booster station, the combined station and the like do not have natural gas purification treatment devices, and the flow fluctuation of associated gas directly conveyed to the stations is large, so that the associated gas is not beneficial to continuous use; associated gas mostly contains non-hydrocarbon compounds such as moisture, carbon dioxide, hydrogen sulfide, mechanical impurities and the like, and is not sufficient to be directly used as fuel for combustion, the hydrocarbon organic matter content in combustion waste gas is high, and the environment is polluted; meanwhile, the damage to the heating furnace is serious, and the combustion efficiency is continuously reduced. Therefore, the associated gas directly used as fuel gas has the hazards of wasting resources, polluting the environment and damaging a heating device. Based on the technical scheme, the invention provides a method for treating associated gas of an oil field operation station, which is used for solving the technical defect of using the associated gas as fuel gas.
Disclosure of Invention
In order to overcome the problems, the invention provides a method for improving the utilization efficiency of associated gas of an oil field operation station, which improves the combustion efficiency of the associated gas, reduces the discharge amount of organic waste gas and sulfur dioxide, and simultaneously prolongs the service life of pipelines and combustion furnaces of the operation station.
The technical scheme adopted by the invention is as follows:
a method for improving utilization efficiency of associated gas of an oil field operation station comprises the following specific steps: adding a gas absorption device and a dryer at the front end of an inlet of associated gas entering a heating furnace, wherein an absorbent is filled in the gas absorption device, and a drying agent is filled in the dryer; the gas separated by the three-phase separator of the station depends on the system pressure of the separator, firstly, the gas is desulfurized and decarbonized for the first-stage purification by the absorbent in the gas absorption device at normal temperature, and then, the gas is dehydrated for the second-stage purification by the dryer at normal temperature and then enters the heating furnace to be used as fuel gas.
The gas absorption device is a mixed organic amine absorption device.
The method for desulfurizing and decarbonizing the associated gas in the mixed organic amine absorption device comprises the following steps: removing hydrogen sulfide and carbon dioxide gas in the associated gas by adopting mixed organic amine; the total amine concentration in the mixed organic amine is not more than 10 mol/L.
Preparing mixed organic amine absorption liquid according to the volume amount of the absorbent to be loaded under the normal working condition of the gas absorption device; the mixed organic amine absorption liquid comprises the following components in volume ratio: 3-5mol/L of N-methyldiethanolamine, 1.5-3mol/L of triethylene tetramine, 1.0-2.0mol/L of piperazine and a solvent, wherein the solvent is deionized water, mixed organic amine absorption liquid obtained by mixing according to the proportion is used as an absorbent, and the prepared absorbent is moved into a gas absorption device.
The drying agent in the dryer is a potassium-containing A-type zeolite molecular sieve.
The pore diameter of the potassium A-type zeolite molecular sieve is about 0.3 nm.
The absorbent is replaceable, and the replacement method comprises the following steps: testing gas at the outlet of the gas absorption device by using pH test paper, if the pH value is approximately equal to 7, replacing the absorbent, wherein the absorbent is prepared when the absorbent is replaced; the replaced absorbent is sent to a raw material manufacturer for recycling and regeneration.
The invention has the beneficial effects that:
the method is applied to a two-stage purification process without phase change of the associated gas, and a gas absorption device and a dryer are added at the front end of an inlet of the associated gas into a heating furnace. Associated gas is subjected to primary purification of desulfurization and decarbonization through a mixed organic amine absorption device at normal temperature, and is subjected to secondary purification of dehydration through a potassium-containing A-type zeolite molecular sieve dryer at normal temperature, and then enters a heating furnace to be used as fuel gas, so that the combustion efficiency of the associated gas is improved, the discharge amount of organic waste gas and sulfur dioxide is reduced, and the service life of an operation field station pipeline and a combustion furnace is prolonged. According to the method provided by the invention, the removal rates of carbon dioxide and water vapor are both more than 97%, hydrogen sulfide and other sulfur-containing gases are not detected in the fuel gas entering the heating furnace, and carbon deposit, water accumulation and corrosion conditions are not found in related gathering pipelines and the heating furnace. The whole treatment process is simple, and the treatment effect is superior to that of a large natural gas treatment plant.
Detailed Description
Example 1:
in order to overcome the problems, the invention provides a method for improving the utilization efficiency of associated gas of an oil field operation station, which improves the combustion efficiency of the associated gas, reduces the discharge amount of organic waste gas and sulfur dioxide, and simultaneously prolongs the service life of pipelines and combustion furnaces of the operation station.
A method for improving utilization efficiency of associated gas of an oil field operation station comprises the following specific steps: adding a gas absorption device and a dryer at the front end of an inlet of associated gas entering a heating furnace, wherein an absorbent is filled in the gas absorption device, and a drying agent is filled in the dryer; the gas separated by the three-phase separator of the station depends on the system pressure of the separator, firstly, the gas is desulfurized and decarbonized for the first-stage purification by the absorbent in the gas absorption device at normal temperature, and then, the gas is dehydrated for the second-stage purification by the dryer at normal temperature and then enters the heating furnace to be used as fuel gas.
The method mainly applies a two-stage purification process without phase change of the associated gas, and a gas absorption device and a dryer are added at the front end of an inlet of a heating furnace for the associated gas. The field station three-phase separator separates gas and relies on the system pressure of separator, loop through the mixed organic amine absorbing device that total concentration is not more than 10mol/L and carry out desulfurization decarbonization first grade purification at normal temperature, after the dehydration second grade purification is carried out to potassium A type zeolite molecular sieve desicator normal atmospheric temperature, reentrant heating furnace uses as fuel gas and uses as fuel gas, improves associated gas combustion efficiency, reduces organic waste gas and sulfur dioxide emission, prolongs operation field station pipeline and combustion furnace service life simultaneously.
Example 2:
based on embodiment 1, in this embodiment, preferably, the gas absorbing device is a hybrid organic amine absorbing device.
Preferably, the method for desulfurizing and decarbonizing the associated gas in the mixed organic amine absorption device comprises the following steps: removing hydrogen sulfide and carbon dioxide gas in the associated gas by adopting mixed organic amine; the total amine concentration in the mixed organic amine is not more than 10 mol/L.
Preferably, preparing a mixed organic amine absorption liquid according to the volume of the absorbent to be loaded under the normal working condition of the gas absorption device; the mixed organic amine absorption liquid comprises the following components in volume ratio: 3-5mol/L of N-methyldiethanolamine, 1.5-3mol/L of triethylene tetramine, 1.0-2.0mol/L of piperazine and a solvent, wherein the solvent is deionized water, mixed organic amine absorption liquid obtained by mixing according to the proportion is used as an absorbent, and the prepared absorbent is moved into a gas absorption device.
Preferably, the drying agent in the dryer is a potassium-containing A-type zeolite molecular sieve.
Preferably, the potassium A type zeolite molecular sieve has a pore diameter of about 0.3 nm.
In the invention, the associated gas dehydration technology comprises the following steps: and removing water vapor in the associated gas by adopting a potassium-containing A-type zeolite molecular sieve with a low silicon-aluminum ratio. The potassium-containing A-type zeolite molecular sieve is a strong polar hydrophilic material, the diameter of a pore channel is about 0.3nm, polar water molecules in associated gas can freely enter and be absorbed and adsorbed, and hydrocarbon molecules are nonpolar substances and are not absorbed and adsorbed. Low silicon to aluminum ratio definition: Si/Al is 1.0-1.1; the mass ratio of SiO2/Al2O3 in the invention is 1.16-1.20.
Preferably, the absorbent is replaceable, and the replacement method comprises the following steps: testing gas at the outlet of the gas absorption device by using pH test paper, if the pH value is approximately equal to 7, replacing the absorbent, wherein the absorbent is prepared when the absorbent is replaced; the replaced absorbent is sent to a raw material manufacturer for recycling and regeneration.
After the process transformation and the installation and operation of treatment facilities, the method mainly replaces the mixed organic amine absorbent and regenerates the desiccant potassium-containing A-type zeolite molecular sieve in the implementation process.
1. Measuring and calculating the associated gas generation amount under the normal working conditions (normal working temperature and working pressure) of the three-phase separator of the operation station, and purchasing and installing a gas absorption device with corresponding processing capacity and a drying device (containing a potassium A-type zeolite molecular sieve) with a self-heating function.
2. The method comprises the following steps of purchasing commercially available N-methyldiethanolamine, triethylene tetramine and piperazine finished products, and preparing mixed organic amine absorption liquid according to the volume amount of the absorbent which needs to be loaded under the normal working condition of an absorption device: 3-5 mol/LN-Methyldiethanolamine (MDEA) +1.5-3mol/L triethylene tetramine (TETA) +1.0-2.0mol/L Piperazine (PZ), deionized water is used as a solvent, the prepared mixed organic amine solution is moved into an absorption device, and the whole purification system can be started.
3. And (3) replacing the absorbent: and testing the gas at the outlet of the gas absorption device by using pH test paper, and if the pH value is approximately equal to 7, replacing the absorbent, wherein the absorbent is prepared when the absorbent is replaced. The replaced absorbent is sent to a raw material manufacturer for recycling and regeneration.
4. Drying agent regeneration treatment: the regeneration period was 2 weeks. The regeneration method comprises the steps of opening a bypass valve to bypass gas, opening an electric heating switch of a dryer, heating to 105 ℃, keeping for 2-3 hours, closing a heating power supply to recover to normal temperature to complete desiccant regeneration, and closing the bypass valve to recover to normal working conditions.
The method is applied to a two-stage purification process without phase change of the associated gas, and a gas absorption device and a dryer are added at the front end of an inlet of the associated gas into a heating furnace. Associated gas is subjected to primary purification of desulfurization and decarbonization through a mixed organic amine absorption device at normal temperature, and is subjected to secondary purification of dehydration through a potassium-containing A-type zeolite molecular sieve dryer at normal temperature, and then enters a heating furnace to be used as fuel gas, so that the combustion efficiency of the associated gas is improved, the discharge amount of organic waste gas and sulfur dioxide is reduced, and the service life of an operation field station pipeline and a combustion furnace is prolonged.
2017 and 2018, 2 pressurizing stations and 1 combined station of the Changqing oil field are subjected to engineering transformation according to the content of patent requirements, associated gas separated by a three-phase separator is subjected to evolution treatment, the removal rate of carbon dioxide and water vapor is more than 97 percent after two years of operation under the condition of not changing the original gathering and transportation process parameters, hydrogen sulfide and other sulfur-containing gases are not detected in fuel gas entering a heating furnace, and carbon deposit, water accumulation and corrosion conditions are not found in related gathering and transportation pipelines and the heating furnace. The whole treatment process is simple, and the treatment effect is superior to that of a large natural gas treatment plant.
Example 3:
based on embodiment 1 or 2, in this embodiment, preferably, the mixed organic amine absorption liquid is prepared according to the volume amount of the absorbent to be loaded by the gas absorption apparatus under normal working conditions; the mixed organic amine absorption liquid comprises the following components in volume ratio: 3mol/L of N-methyldiethanolamine, 1.5mol/L of triethylene tetramine, 1.0mol/L of piperazine and a solvent, wherein the solvent is deionized water, mixed organic amine absorption liquid obtained by mixing according to the proportion is used as an absorbent, and the prepared absorbent is moved into a gas absorption device. After the absorbent provided by the embodiment is applied, the removal rate of carbon dioxide is 98%.
Example 4:
based on embodiment 1 or 2, in this embodiment, preferably, the mixed organic amine absorption liquid is prepared according to the volume amount of the absorbent to be loaded by the gas absorption apparatus under normal working conditions; the mixed organic amine absorption liquid comprises 5mol/L N-methyldiethanolamine, 3mol/L triethylene tetramine, 2.0mol/L piperazine and a solvent according to the volume ratio, the solvent is deionized water, the mixed organic amine absorption liquid obtained by mixing according to the proportion is used as an absorbent, and the prepared absorbent is moved into a gas absorption device. After the absorbent provided by the embodiment is applied, the removal rate of carbon dioxide is 99%.
Example 5:
based on embodiment 1 or 2, in this embodiment, preferably, the mixed organic amine absorption liquid is prepared according to the volume amount of the absorbent to be loaded by the gas absorption apparatus under normal working conditions; the mixed organic amine absorption liquid comprises the following components in volume ratio: 4mol/L of N-methyldiethanolamine, 2mol/L of triethylene tetramine, 1.5mol/L of piperazine and a solvent, wherein the solvent is deionized water, mixed organic amine absorption liquid obtained by mixing according to the proportion is used as an absorbent, and the prepared absorbent is moved into a gas absorption device. After the absorbent provided by the embodiment is applied, the removal rate of carbon dioxide is 98%.
As shown in examples 4-6, the invention selects the absorbents prepared under different proportions, then carries out the carbon dioxide removal experiment indoors, and records the removal rate of the absorbents under different proportions to the carbon dioxide. The carbon dioxide removing rate of the absorbent provided by the invention is more than 97%. The removal rate of the desiccant to the water vapor is over 97 percent. In the present invention, the experimental procedures for detailed description are prior art, and will not be further described in the present invention.
The above examples are merely illustrative of the present invention and should not be construed as limiting the scope of the invention, and all designs identical or similar to the present invention are within the scope of the invention. The structure of the apparatus and the method steps not described in detail in the embodiments are well known in the art and will not be described herein.
Claims (7)
1. A method for improving the utilization efficiency of associated gas of an oil field operation station is characterized by comprising the following steps: the method comprises the following specific steps: adding a gas absorption device and a dryer at the front end of an inlet of associated gas entering a heating furnace, wherein an absorbent is filled in the gas absorption device, and a drying agent is filled in the dryer; the gas separated by the three-phase separator of the station depends on the system pressure of the separator, firstly, the gas is desulfurized and decarbonized for the first-stage purification by the absorbent in the gas absorption device at normal temperature, and then, the gas is dehydrated for the second-stage purification by the dryer at normal temperature and then enters the heating furnace to be used as fuel gas.
2. The method for improving the utilization efficiency of associated gas of an oilfield operation field station according to claim 1, wherein the method comprises the following steps: the gas absorption device is a mixed organic amine absorption device.
3. The method for improving the utilization efficiency of the associated gas of the oilfield operation field station according to claim 2, wherein the method comprises the following steps: the method for desulfurizing and decarbonizing the associated gas in the mixed organic amine absorption device comprises the following steps: removing hydrogen sulfide and carbon dioxide gas in the associated gas by adopting mixed organic amine; the total amine concentration in the mixed organic amine is not more than 10 mol/L.
4. The method for improving the utilization efficiency of associated gas of an oilfield operation field station according to claim 1, wherein the method comprises the following steps: preparing mixed organic amine absorption liquid according to the volume amount of the absorbent to be loaded under the normal working condition of the gas absorption device; the mixed organic amine absorption liquid comprises the following components in volume ratio: 3-5mol/L of N-methyldiethanolamine, 1.5-3mol/L of triethylene tetramine, 1.0-2.0mol/L of piperazine and a solvent, wherein the solvent is deionized water, mixed organic amine absorption liquid obtained by mixing according to the proportion is used as an absorbent, and the prepared absorbent is moved into a gas absorption device.
5. The method for improving the utilization efficiency of associated gas of an oilfield operation field station according to claim 1, wherein the method comprises the following steps: the drying agent in the dryer is a potassium-containing A-type zeolite molecular sieve.
6. The method for improving the utilization efficiency of the associated gas of the oilfield operation field station according to claim 5, wherein the method comprises the following steps: the pore diameter of the potassium A-type zeolite molecular sieve is about 0.3 nm.
7. The method for improving the utilization efficiency of associated gas of an oilfield operation field station according to claim 1, wherein the method comprises the following steps: the absorbent is replaceable, and the replacement method comprises the following steps: testing gas at the outlet of the gas absorption device by using pH test paper, if the pH value is approximately equal to 7, replacing the absorbent, wherein the absorbent is prepared when the absorbent is replaced; the replaced absorbent is sent to a raw material manufacturer for recycling and regeneration.
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