CN113772672A - Fire flooding oil extraction tail gas carbon emission reduction treatment method - Google Patents
Fire flooding oil extraction tail gas carbon emission reduction treatment method Download PDFInfo
- Publication number
- CN113772672A CN113772672A CN202111116368.0A CN202111116368A CN113772672A CN 113772672 A CN113772672 A CN 113772672A CN 202111116368 A CN202111116368 A CN 202111116368A CN 113772672 A CN113772672 A CN 113772672A
- Authority
- CN
- China
- Prior art keywords
- tail gas
- gas
- tank
- plasma
- unit
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
- 238000000034 method Methods 0.000 title claims abstract description 24
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 title claims abstract description 14
- 229910052799 carbon Inorganic materials 0.000 title claims abstract description 14
- 238000000605 extraction Methods 0.000 title claims abstract description 8
- 230000009467 reduction Effects 0.000 title claims abstract description 7
- 239000007789 gas Substances 0.000 claims abstract description 112
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 43
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims abstract description 37
- 239000002253 acid Substances 0.000 claims abstract description 29
- 238000001179 sorption measurement Methods 0.000 claims abstract description 24
- 229910001868 water Inorganic materials 0.000 claims abstract description 24
- 238000002407 reforming Methods 0.000 claims abstract description 23
- QGZKDVFQNNGYKY-UHFFFAOYSA-N Ammonia Chemical compound N QGZKDVFQNNGYKY-UHFFFAOYSA-N 0.000 claims abstract description 19
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 claims abstract description 19
- 229910002091 carbon monoxide Inorganic materials 0.000 claims abstract description 17
- 150000003863 ammonium salts Chemical class 0.000 claims abstract description 15
- 238000001816 cooling Methods 0.000 claims abstract description 15
- 229910052757 nitrogen Inorganic materials 0.000 claims abstract description 15
- 239000001257 hydrogen Substances 0.000 claims abstract description 9
- 229910052739 hydrogen Inorganic materials 0.000 claims abstract description 9
- 229910021529 ammonia Inorganic materials 0.000 claims abstract description 8
- 239000007787 solid Substances 0.000 claims abstract description 7
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 claims abstract description 6
- MWUXSHHQAYIFBG-UHFFFAOYSA-N nitrogen oxide Inorganic materials O=[N] MWUXSHHQAYIFBG-UHFFFAOYSA-N 0.000 claims abstract description 3
- 239000002904 solvent Substances 0.000 claims abstract description 3
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims description 52
- 229910002092 carbon dioxide Inorganic materials 0.000 claims description 27
- 239000001569 carbon dioxide Substances 0.000 claims description 25
- 239000007788 liquid Substances 0.000 claims description 24
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 23
- QAOWNCQODCNURD-UHFFFAOYSA-N sulfuric acid group Chemical group S(O)(O)(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-N 0.000 claims description 16
- 239000008367 deionised water Substances 0.000 claims description 11
- 229910021641 deionized water Inorganic materials 0.000 claims description 11
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 claims description 10
- 239000003513 alkali Substances 0.000 claims description 10
- 239000012670 alkaline solution Substances 0.000 claims description 10
- 239000000243 solution Substances 0.000 claims description 10
- 230000018044 dehydration Effects 0.000 claims description 9
- 238000006297 dehydration reaction Methods 0.000 claims description 9
- 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
- 150000002500 ions Chemical class 0.000 claims description 6
- 230000008569 process Effects 0.000 claims description 6
- 229920006395 saturated elastomer Polymers 0.000 claims description 6
- 238000005406 washing Methods 0.000 claims description 6
- AXCZMVOFGPJBDE-UHFFFAOYSA-L calcium dihydroxide Chemical compound [OH-].[OH-].[Ca+2] AXCZMVOFGPJBDE-UHFFFAOYSA-L 0.000 claims description 5
- 238000003795 desorption Methods 0.000 claims description 5
- 239000002245 particle Substances 0.000 claims description 5
- NBIIXXVUZAFLBC-UHFFFAOYSA-N Phosphoric acid Chemical compound OP(O)(O)=O NBIIXXVUZAFLBC-UHFFFAOYSA-N 0.000 claims description 4
- KWYUFKZDYYNOTN-UHFFFAOYSA-M Potassium hydroxide Chemical group [OH-].[K+] KWYUFKZDYYNOTN-UHFFFAOYSA-M 0.000 claims description 4
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 claims description 4
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 claims description 4
- 239000001301 oxygen Substances 0.000 claims description 4
- 229910052760 oxygen Inorganic materials 0.000 claims description 4
- 230000005484 gravity Effects 0.000 claims description 3
- 150000002431 hydrogen Chemical class 0.000 claims description 3
- 230000007935 neutral effect Effects 0.000 claims description 3
- 239000012266 salt solution Substances 0.000 claims description 3
- 238000003860 storage Methods 0.000 claims description 3
- 238000006276 transfer reaction Methods 0.000 claims description 3
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 claims description 2
- 230000009471 action Effects 0.000 claims description 2
- 229910000147 aluminium phosphate Inorganic materials 0.000 claims description 2
- 238000002242 deionisation method Methods 0.000 claims description 2
- 239000001294 propane Substances 0.000 claims description 2
- 238000006555 catalytic reaction Methods 0.000 claims 1
- 229910001873 dinitrogen Inorganic materials 0.000 claims 1
- 238000009833 condensation Methods 0.000 abstract description 2
- 230000005494 condensation Effects 0.000 abstract description 2
- 238000007710 freezing Methods 0.000 abstract description 2
- 230000008014 freezing Effects 0.000 abstract description 2
- 239000003921 oil Substances 0.000 description 13
- 238000011084 recovery Methods 0.000 description 7
- 238000006243 chemical reaction Methods 0.000 description 5
- 239000010779 crude oil Substances 0.000 description 4
- BIGPRXCJEDHCLP-UHFFFAOYSA-N ammonium bisulfate Chemical compound [NH4+].OS([O-])(=O)=O BIGPRXCJEDHCLP-UHFFFAOYSA-N 0.000 description 3
- BFNBIHQBYMNNAN-UHFFFAOYSA-N ammonium sulfate Chemical compound N.N.OS(O)(=O)=O BFNBIHQBYMNNAN-UHFFFAOYSA-N 0.000 description 3
- 229910052921 ammonium sulfate Inorganic materials 0.000 description 3
- 235000011130 ammonium sulphate Nutrition 0.000 description 3
- 230000003197 catalytic effect Effects 0.000 description 3
- 238000010586 diagram Methods 0.000 description 3
- 239000000203 mixture Substances 0.000 description 3
- 239000000920 calcium hydroxide Substances 0.000 description 2
- 229910001861 calcium hydroxide Inorganic materials 0.000 description 2
- 238000004581 coalescence Methods 0.000 description 2
- 238000010494 dissociation reaction Methods 0.000 description 2
- 230000005593 dissociations Effects 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 238000010891 electric arc Methods 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 230000007613 environmental effect Effects 0.000 description 2
- 239000003344 environmental pollutant Substances 0.000 description 2
- 239000003546 flue gas Substances 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 238000012856 packing Methods 0.000 description 2
- 231100000719 pollutant Toxicity 0.000 description 2
- 239000010865 sewage Substances 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- 241000521257 Hydrops Species 0.000 description 1
- 206010030113 Oedema Diseases 0.000 description 1
- 238000010793 Steam injection (oil industry) Methods 0.000 description 1
- 150000007513 acids Chemical class 0.000 description 1
- 230000004075 alteration Effects 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000000903 blocking effect Effects 0.000 description 1
- 239000003518 caustics Substances 0.000 description 1
- 238000005119 centrifugation Methods 0.000 description 1
- 238000002485 combustion reaction Methods 0.000 description 1
- 239000000498 cooling water Substances 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 238000006477 desulfuration reaction Methods 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 238000001914 filtration Methods 0.000 description 1
- 239000005431 greenhouse gas Substances 0.000 description 1
- 238000006386 neutralization reaction Methods 0.000 description 1
- QJGQUHMNIGDVPM-UHFFFAOYSA-N nitrogen(.) Chemical compound [N] QJGQUHMNIGDVPM-UHFFFAOYSA-N 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 239000000779 smoke Substances 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
- 238000009423 ventilation Methods 0.000 description 1
- 239000002699 waste material Substances 0.000 description 1
Images
Classifications
-
- C—CHEMISTRY; METALLURGY
- C01—INORGANIC CHEMISTRY
- C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
- C01B32/00—Carbon; Compounds thereof
- C01B32/40—Carbon monoxide
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/26—Drying gases or vapours
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/26—Drying gases or vapours
- B01D53/266—Drying gases or vapours by filtration
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/34—Chemical or biological purification of waste gases
- B01D53/46—Removing components of defined structure
- B01D53/48—Sulfur compounds
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/34—Chemical or biological purification of waste gases
- B01D53/46—Removing components of defined structure
- B01D53/48—Sulfur compounds
- B01D53/52—Hydrogen sulfide
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/34—Chemical or biological purification of waste gases
- B01D53/74—General processes for purification of waste gases; Apparatus or devices specially adapted therefor
- B01D53/77—Liquid phase processes
- B01D53/79—Injecting reactants
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/34—Chemical or biological purification of waste gases
- B01D53/96—Regeneration, reactivation or recycling of reactants
-
- C—CHEMISTRY; METALLURGY
- C01—INORGANIC CHEMISTRY
- C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
- C01B21/00—Nitrogen; Compounds thereof
- C01B21/04—Purification or separation of nitrogen
- C01B21/0405—Purification or separation processes
-
- C—CHEMISTRY; METALLURGY
- C01—INORGANIC CHEMISTRY
- C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
- C01B25/00—Phosphorus; Compounds thereof
- C01B25/16—Oxyacids of phosphorus; Salts thereof
- C01B25/26—Phosphates
- C01B25/28—Ammonium phosphates
-
- C—CHEMISTRY; METALLURGY
- C01—INORGANIC CHEMISTRY
- C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
- C01B3/00—Hydrogen; Gaseous mixtures containing hydrogen; Separation of hydrogen from mixtures containing it; Purification of hydrogen
- C01B3/02—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen
- C01B3/32—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen by reaction of gaseous or liquid organic compounds with gasifying agents, e.g. water, carbon dioxide, air
- C01B3/34—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen by reaction of gaseous or liquid organic compounds with gasifying agents, e.g. water, carbon dioxide, air by reaction of hydrocarbons with gasifying agents
- C01B3/38—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen by reaction of gaseous or liquid organic compounds with gasifying agents, e.g. water, carbon dioxide, air by reaction of hydrocarbons with gasifying agents using catalysts
-
- C—CHEMISTRY; METALLURGY
- C01—INORGANIC CHEMISTRY
- C01C—AMMONIA; CYANOGEN; COMPOUNDS THEREOF
- C01C1/00—Ammonia; Compounds thereof
- C01C1/24—Sulfates of ammonium
- C01C1/242—Preparation from ammonia and sulfuric acid or sulfur trioxide
-
- C—CHEMISTRY; METALLURGY
- C01—INORGANIC CHEMISTRY
- C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
- C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
- C01B2203/02—Processes for making hydrogen or synthesis gas
- C01B2203/0205—Processes for making hydrogen or synthesis gas containing a reforming step
- C01B2203/0227—Processes for making hydrogen or synthesis gas containing a reforming step containing a catalytic reforming step
- C01B2203/0238—Processes for making hydrogen or synthesis gas containing a reforming step containing a catalytic reforming step the reforming step being a carbon dioxide reforming step
-
- C—CHEMISTRY; METALLURGY
- C01—INORGANIC CHEMISTRY
- C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
- C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
- C01B2203/08—Methods of heating or cooling
- C01B2203/0805—Methods of heating the process for making hydrogen or synthesis gas
- C01B2203/0861—Methods of heating the process for making hydrogen or synthesis gas by plasma
-
- C—CHEMISTRY; METALLURGY
- C01—INORGANIC CHEMISTRY
- C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
- C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
- C01B2203/12—Feeding the process for making hydrogen or synthesis gas
- C01B2203/1205—Composition of the feed
- C01B2203/1211—Organic compounds or organic mixtures used in the process for making hydrogen or synthesis gas
- C01B2203/1235—Hydrocarbons
- C01B2203/1241—Natural gas or methane
Landscapes
- Chemical & Material Sciences (AREA)
- Engineering & Computer Science (AREA)
- Organic Chemistry (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Analytical Chemistry (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- General Chemical & Material Sciences (AREA)
- Health & Medical Sciences (AREA)
- Inorganic Chemistry (AREA)
- Environmental & Geological Engineering (AREA)
- Biomedical Technology (AREA)
- Combustion & Propulsion (AREA)
- General Health & Medical Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- Sustainable Development (AREA)
- Treating Waste Gases (AREA)
- Gas Separation By Absorption (AREA)
Abstract
The invention relates to a fire flooding oil extraction tail gas carbon emission reduction treatment method, which comprises the following steps: (1) dewatering the fireflood tail gas by a dewatering unit; (2) reacting the dewatered tail gas through a plasma reforming unit to generate water gas, and reacting hydrogen in the water gas with nitrogen to generate ammonia; (3) ammonia gas in the tail gas is acted by a cooling and dedusting unit to generate ammonium salt, and the solvent is removed to obtain ammonium salt solid; (4) removing residual acid from the reformed tail gas through a deacidification unit; (4) dehydrating and adsorbing the deacidified tail gas by a pressure swing adsorption unit, and separating nitrogen and carbon monoxide; the method can reduce carbon emission, recycle tail gas and solve the problem of freezing of pipelines due to water vapor condensation in winter.
Description
Technical Field
The invention relates to the field of petroleum exploitation tail gas treatment, in particular to a fire flooding oil extraction tail gas carbon emission reduction method.
Background
Fire flooding oil recovery is to inject air into an underground oil layer by adopting a high-pressure fan and ignite and burn the air, the crude oil is pushed to a production well from a steam injection well by heat and smoke generated in the burning process, short-distance displacement recovery of the crude oil is realized, and the fire flooding oil recovery is particularly suitable for thick oil recovery and has the advantages of high heat efficiency utilization rate, high oil recovery rate, low recovery cost, wide oil field application range and the like.
The fireflood tail gas also contains CH besides nitrogen4、CO2、H2S and other media, if not treated, will pollute the atmosphere and cause greenhouse effect. Wherein CH4Without treatment, not only a large amount of non-renewable energy is wasted, but also the carbon emission equivalent (the carbon emission equivalent of methane per ton is 86 times of that of carbon dioxide per ton, and the carbon emission equivalent is calculated according to the influence of emission within 20 years) is increased, and the method is not in accordance with national carbon peak reaching and carbon neutralization environmental policies.
The fireflood tail gas also contains a large amount of water vapor, and if the fireflood tail gas is not treated, the phenomenon of freezing and blocking of a pipeline can occur in winter, so that the system pressurization can be caused, and the fireflood oil recovery efficiency is seriously influenced.
The plasma is the fourth state of the substance, has the characteristics of active particles, high temperature and high energy density, can ensure that the two substances are difficult to react chemically and quickly under common conditions, has the advantages of increasing the chemical reaction rate, saving the reaction cost and the like, and is gradually applied to chemical reactions.
CN 212327831U adopts dehydration-desulfurization-pressure swing adsorption technology to treat fireflood tail gas, and methane is recovered for resource utilization, but carbon dioxide in fireflood is still discharged to the environment, so that carbon emission is increased; CN 108392958A adopts cyclone separator-cooling-desulfurization technology to carry out tail gas treatment and has solved tail gas pipeline hydrops, frozen stifled scheduling problem, but carbon dioxide and methane in the tail gas are not handled, increase the risk of environmental greenhouse effect.
Disclosure of Invention
In order to overcome the defects in the prior art, the invention aims to provide a treatment method for carbon emission reduction of tail gas of fire flooding oil extraction, which can solve the problem that a pipeline is frozen due to water vapor condensation in winter, reduce the amount of oxygen generated by dissociation of water in plasma reforming, eliminate a carbon dioxide generation source, reduce carbon emission and recycle tail gas.
The specific technical scheme is as follows:
A. dewatering the fireflood tail gas by a dewatering unit;
B. reacting the dewatered tail gas through a plasma reforming unit to generate water gas, and reacting hydrogen in the water gas with nitrogen to generate ammonia;
C. ammonia in the tail gas is acted by a cooling and dedusting unit to generate ammonium salt;
D. removing residual acid from the reformed tail gas through a deacidification unit;
E. and dehydrating the deacidification tail gas by a pressure swing adsorption unit, and separating nitrogen and carbon monoxide.
In the step A, the dehydration unit comprises a gas-liquid separator and a precision filter, tail gas discharged from a fire flooding oil extraction inlet is sequentially connected with the gas-liquid separator and the coalescence filter, the tail gas is dehydrated by the gas-liquid separator 1 and the precision filter 3 and then enters the plasma reforming unit, and water removed by the gas-liquid separator 1 and the coalescence filter 3 is converged to the sewage tank 2 for harmless treatment.
Further, the temperature of the gas-liquid separator 1 is 10-50 ℃, preferably 35 ℃, and the pressure is 80-600 KPa, preferably 100-250 KPa.
In the step B, the plasma reforming unit comprises a carbon dioxide reforming tower 4, a plasma torch 6, a plasma power supply 5, a deionized water tank 8, a deionization circulating water pump 7 and an air cooler 9. The dehydrated tail gas enters a carbon dioxide reforming tower 4, carbon dioxide and methane in the tail gas react under the catalytic action of plasma active particles to generate water gas (carbon monoxide is the main component), in order to improve the gas-gas reaction efficiency, the tail gas enters the carbon dioxide reforming tower 4 in a tangential rotational flow mode, a plasma torch 6 is arranged in a position which is opposite to the tangential direction and is 200-500 mm higher than the section of a tail gas inlet (relative to the air inlet direction of the tail gas), the plasma enters the carbon dioxide reforming tower 4, the tail gas and the plasma are fully mixed in the tower, the carbon dioxide and the methane in the tail gas react under the catalytic action of the active particles of the plasma to generate carbon monoxide and hydrogen, and the hydrogen and the nitrogen plasma react to generate ammonia. The plasma torch 6 adopts nitrogen as working medium gas, the plasma cooling adopts deionized water for cooling, the deionized water enters a plasma water tank 8 after heat exchange between a water chamber of the plasma torch and an electric arc channel of the plasma torch, and the deionized water is pumped into an air cooler 9 through an ion passing circulating water pump 7 and is sent into the plasma torch 6 after air cooling heat exchange.
Further, the average temperature of the ion torch is 2000-4000 ℃, preferably 2500-3000 ℃.
In the step C, the cooling and dedusting unit comprises a packed tower 10, an acid liquid tank 11, an acid liquid pump 12 and a centrifuge 14. The reformed tail gas enters a packed tower 10 to flow in a countercurrent manner and carries out mass transfer and heat transfer with an acid solution at the upper end of the packed tower on the packed tower, alkaline gas (mainly ammonia) in the tail gas is absorbed to form an ammonium salt solution, after ammonium salt is saturated, a solvent is removed to obtain an ammonium salt solid, and the separated liquid is conveyed to an acid liquid box.
Further, the acid solution in the packed tower comprises one or more of the following acids, sulfuric acid and phosphoric acid, preferably sulfuric acid.
Further, the concentration range of the sulfuric acid solution is 1-20 mol/L, preferably 5-10 mol/L.
Further, obtaining the ammonium salt solid means that the liquid in the saturated ammonium salt is removed by the bag, and the solid part is remained, and the method includes but is not limited to: filtration, centrifugation and the like may be used alone or in combination with other conventional means for removing a liquid.
And D, the deacidification unit comprises an alkaline washing tower 15, an alkaline solution tank 16 and an alkaline solution pump 17, the tail gas is cooled to the normal temperature after passing through a packing tower 10 and then is sent to the deacidification unit to remove residual acid gas of the tail gas, the alkaline washing tower 15 also adopts the packing tower, the tail gas is subjected to mass transfer and heat transfer reaction with alkaline solution in a countercurrent mode, the alkaline solution absorbing the residual acid flows into the alkaline solution tank 16 by gravity and then is conveyed to the alkaline washing tower 15 through the alkaline solution pump to be circularly sprayed, washed and absorbed with the residual acid, a PH meter is arranged on the alkaline solution tank 16, when the PH value is reduced to be neutral, a part of liquid is discharged, and new alkaline solution is replenished into the tank.
Further, the alkali in the caustic tower 15 may be selected from one or more of the following: potassium hydroxide, sodium hydroxide, calcium hydroxide, preferably calcium hydroxide.
In step E, the pressure swing adsorption unit comprises a compressor 18, a dehydration tank 19 and an adsorption tank 20. The tail gas absorbing the residual acid directly enters a pressure swing adsorption unit, the deacidified tail gas is pressurized by a compressor 18 and then is sent to a dehydration tank 19, the tail gas is dehydrated in the dehydration tank 19 and then enters a pressure swing adsorption tank 20, the pressure swing adsorption adopts two towers for operation, one tower is in a feeding adsorption state, the other tower is in a desorption state, and all the technical processes of adsorption, pressure equalizing and reducing, desorption and pressure equalizing and increasing are completed. And one part of desorbed nitrogen is used as working medium gas of the plasma torch, the other part of gas is discharged in an emptying way, and the desorbed carbon monoxide is sent to a carbon monoxide storage tank for resource utilization.
Furthermore, in the pressure swing adsorption process, the pressure range is 400-800 KPa, preferably 500-600 KPa.
Compared with the prior art, the technical scheme of the invention has the following remarkable beneficial effects:
(1) according to the invention, methane and carbon dioxide in the fireflood tail gas are subjected to plasma reforming to obtain carbon monoxide and ammonium salt, and the carbon monoxide and the ammonium salt can be recycled, so that the aim of reducing greenhouse gas emission is achieved.
(2) The dehydration unit added in the invention can remove moisture in the fireflood tail gas in time, keep the ventilation pipeline smooth even in winter, and simultaneously reduce the dissociation of water into oxygen in plasma reforming, thereby avoiding the generation source of carbon dioxide.
(3) Adopt the deionized water circulation water supply system in the ion reforming unit, can use cooling water circulation, reduced the waste to the water resource.
(4) In the specific embodiment of the invention, the deacidification unit can not only remove the hydrogen sulfide in the tail gas, but also remove the sulfuric acid gas carried out in the cooling and dedusting unit.
Drawings
FIG. 1 is a schematic structural view of the present invention;
FIG. 2 is a schematic diagram of a plasma reforming unit;
FIG. 3 is a schematic structural diagram of a cooling and dedusting unit;
figure 4 is a schematic diagram of a deacidification unit.
1-a gas-liquid separator; 2-a sewage tank; 3-a coalescing filter; 4-a carbon dioxide reforming column; 5-plasma power supply; 6-plasma torch; 7-deionized water pump; 8-a deionized water tank; 9-air cooler; 10-cooling and dedusting tower; 11-acid liquor tank; 12-acid liquid pump; 13-a concentrated liquid pump; 14-a centrifuge; 15-an alkaline washing tower; 16-lye tanks; 17-lye pump; 18-a compressor; 19-a dewatering tank; 20-an adsorption tank; 21-tail gas conveying pipe; 22-nitrogen outlet pipe.
Detailed Description
The embodiments of the present invention will be described in conjunction with the accompanying drawings, and it should be understood that the embodiments described herein are only for the purpose of illustrating and explaining the present invention, and are not intended to limit the present invention.
The fireflood is to artificially inject high-pressure air into the stratum continuously and ignite the air to form a combustion zone, so that the crude oil is cracked, distilled and reduced in viscosity to achieve the aim of crude oil exploitation. And the oxygen in the air is consumed to form flue gas which is discharged through a production well, the components of the flue gas mainly comprise nitrogen, methane, carbon dioxide, carbon monoxide, ethane, propane, hydrogen sulfide, saturated steam and the like, and the nitrogen, the methane and the carbon dioxide are mainly the saturated steam and account for more than 97 percent. The tail gas composition of a certain oil field fireflood well is shown in table 1:
TABLE 1 Tail gas composition of fireflood wells
| CO2(％) | N2(％) | H2O(％) | CH4(％) | O2(％) | CO(％) | H2S(mg/m3) |
| 12.01 | 50.97 | 19.1 | 12.98 | 0.96 | 0.92 | 72.1 |
From the components of the tail gas, the water vapor accounts for 19.1% of the tail gas, and the water vapor has an influence on the tail gas treatment: in winter, water vapor condenses when cooled, and can condense into ice along with temperature reduction to cause pipeline blockage. Therefore, the water vapor in the tail gas needs to be separated.
The tail gas discharged from the fireflood oil extraction inlet is sequentially connected with a gas-liquid separator 1 and a coalescing filter 3 to separate water vapor in the tail gas, the temperature of the gas-liquid separator is 35 ℃, the pressure is 175KPa, and the water content (the water content is more than 2.5 g/Nm) in the tail gas can be adjusted3) Down to < 0.5g/Nm3. The moisture removed by the gas-liquid separator 1 and the coalescing filter 3 is subjected to innocent treatment.
The dehydrated tail gas enters a carbon dioxide reforming tower 4, carbon dioxide and methane in the tail gas react under the catalytic action of plasma active particles to generate carbon monoxide and hydrogen, the hydrogen further reacts with nitrogen plasma to generate ammonia, in order to improve the reaction efficiency of the gas, the tail gas enters the carbon dioxide reforming tower 4 in a tangential rotational flow mode, plasma torches (the average temperature of the plasma torches is 3000 ℃) enable plasma to enter the carbon dioxide reforming tower 4 in an anti-tangential mode and are arranged at positions 300mm higher than the section of a tail gas inlet (relative to the air inlet direction of the tail gas), and the tail gas and the plasma are fully mixed in the tower. The plasma torch 6 adopts nitrogen as working medium gas, the plasma cooling adopts deionized water for cooling, the deionized water enters a plasma water tank 8 after heat exchange between a water chamber of the plasma torch 6 and an electric arc channel of the plasma torch, and the deionized water is pumped into an air cooler 9 through an ion passing circulating water pump 7 and is sent into the plasma torch 6 after air cooling and heat exchange.
The reformed tail gas enters a packed tower 10 to flow reversely and is subjected to mass and heat transfer on the packed tower 10 with 7.5mol/L sulfuric acid solution at the upper end of the packed tower, ammonia gas in the tail gas is absorbed to form solution of ammonium sulfate and ammonium bisulfate, the ammonium sulfate and the ammonium bisulfate are saturated and then are sent to a centrifugal machine 14, the ammonium sulfate and ammonium bisulfate solids are thrown out for bagging under the action of high-speed centrifugal force of the centrifugal machine 14, and the separated liquid is conveyed to an acid liquor box 11.
The tail gas is cooled to normal temperature by a packed tower 10 and then sent to a deacidification unit to remove residual acid gas in a cooling and dedusting unit, the residual acid is mainly hydrogen sulfide and sulfuric acid, a packed tower is also adopted as an alkaline tower 15, saturated calcium hydroxide solution is selected as alkaline liquor, the tail gas and the alkaline liquor are subjected to mass transfer and heat transfer reaction in a countercurrent mode, the alkaline liquor absorbing the residual acid flows into an alkaline liquor tank 16 from gravity and then is conveyed to the alkaline tower 15 by an alkaline liquor pump 17 to be circularly sprayed, washed and absorbed with the residual acid, a pH meter is arranged on the alkaline liquor tank 16, when the pH value is reduced to be neutral, a part of liquid is discharged, and new alkaline liquor is replenished into the tank.
The tail gas absorbing the residual acid directly enters a pressure swing adsorption unit, the deacidified tail gas is pressurized by a compressor 18 and then is sent to a dehydration tank 19, the tail gas is dehydrated in the dehydration tank 19 and then enters a pressure swing adsorption tank 20, the pressure swing adsorption adopts two towers for operation, one tower is in a feeding adsorption state, the other tower is in an analytic state, all the technical processes are adsorption, pressure equalizing and reducing, desorption and pressure equalizing and increasing, and the pressure swing range is 500-600 KPa. One part of desorbed nitrogen is used as working medium gas of the plasma torch 6, the other part of gas is discharged after being emptied, and the desorbed carbon monoxide is sent to a carbon monoxide storage tank for resource utilization.
After the treatment of the steps, the discharged tail gas meets the discharge requirements of the comprehensive emission standard of atmospheric pollutants GB 16297 + 1996 and the emission standard of foul pollutants GB 14554 + 1993 in the second type of regions, and the components and the proportion of the discharged tail gas are shown in Table 2.
TABLE 2 composition and proportion of exhaust gas
The above description is further intended to describe the present invention in detail with reference to specific embodiments, and it should not be construed that the specific embodiments of the present invention are limited to these descriptions. It will be apparent to those skilled in the art that various changes, substitutions and alterations can be made without departing from the spirit and scope of the invention.
Claims (10)
1. The fire flooding oil extraction tail gas carbon emission reduction treatment method is characterized by comprising the following steps:
A. dewatering the fireflood tail gas by a dewatering unit;
B. reacting the dewatered tail gas through a plasma reforming unit to generate water gas, and reacting hydrogen in the water gas with nitrogen to generate ammonia;
C. ammonia gas in the tail gas is acted by a cooling and dedusting unit to generate ammonium salt, and the solvent is removed to obtain ammonium salt solid;
D. removing residual acid from the reformed tail gas through a deacidification unit;
E. the deacidification tail gas is dehydrated and adsorbed by a pressure swing adsorption unit, and nitrogen and carbon monoxide are separated.
2. The method according to claim 1, wherein the dehydration unit in step a comprises a gas-liquid separator (1), a sump (2), a fine filter (3); the plasma reforming unit in the step B comprises a carbon dioxide reforming tower (4), a plasma power supply (5), a plasma torch (6), a deionization circulating water pump (7), a deionized water tank (8) and an air cooler (9); the cooling and dedusting unit in the step C comprises a packed tower (10), an acid liquor box (11), an acid liquor pump (12), a concentrated liquor pump (13) and a centrifuge (14); the deacidification unit in the step D comprises an alkaline washing tower (15), an alkaline solution tank (16), an alkaline solution pump (17) and a compressor (18); a dehydration tank (19), an adsorption tank (20), a tail gas conveying pipe (21) and a nitrogen gas discharge pipe (22).
3. The method according to claims 1 and 2, characterized in that the temperature of the gas-liquid separator (1) in step a is 10 to 50 ℃, preferably 35 ℃; the pressure is 80 to 600KPa, preferably 100 to 250 KPa.
4. The method according to claims 1 and 2, wherein the tail gas in the step B is fully mixed with the plasma in the carbon dioxide reforming tower (4), the carbon dioxide and the methane in the tail gas react under the catalysis of active particles of the plasma to generate carbon monoxide and hydrogen, the hydrogen further reacts with the active ions of the plasma to generate ammonia, the average temperature of the ion torch is 2000-4000 ℃, preferably 2500-3000 ℃, and the working medium gas adopted by the plasma torch is nitrogen.
5. The process according to claims 1 and 2, wherein the off-gas enters the carbon dioxide reforming tower (4) in step B in a tangential swirling flow, and the plasma torch (6) is arranged in a position opposite to and higher than the cross section of the off-gas inlet so that the plasma enters the carbon dioxide reforming tower (4), and the distance between the plasma torch and the cross section of the off-gas inlet is 200-500 mm, preferably 300 mm.
6. The method as claimed in claims 1 and 2, wherein the reformed tail gas in step C enters a packed tower (10) to perform mass and heat transfer with acid liquor at the upper end of the packed tower in the countercurrent manner, alkaline gas in the tail gas is absorbed to form ammonium salt solution, the ammonium salt solution is saturated and then sent to a centrifuge (14), ammonium salt solid is thrown out for bagging under the action of the centrifuge (14), and the separated liquid is sent to an acid liquor tank (11), wherein the acid liquor is sulfuric acid solution and phosphoric acid solution, preferably sulfuric acid solution; the concentration range of the acid solution is 1-20 mol/L, preferably 5-10 mol/L.
7. The method according to claim 1 and 2, characterized in that in step D, the tail gas and the alkali liquor are subjected to mass and heat transfer reaction, the flow direction of the tail gas and the alkali liquor is opposite, the alkali liquor absorbing the residual acid flows into the alkali liquor tank (16) from gravity and then is conveyed to the alkali washing tower (15) through the alkali liquor pump (17) to be circularly sprayed and washed to absorb the residual acid, the alkali liquor tank (16) is provided with a pH meter, when the pH value is reduced to be neutral, a part of liquid is discharged, and new alkali liquor is replenished into the tank, wherein the alkali liquor is potassium hydroxide solution, sodium hydroxide solution, calcium hydroxide solution, preferably saturated calcium hydroxide solution.
8. The method as claimed in claims 1 and 2, characterized in that the deacidified tail gas is pressurized by a compressor (18) and then sent to a dewatering tank (19), the tail gas is dewatered in the dewatering tank (19) and then sent to a pressure swing adsorption tank (20), the pressure swing adsorption adopts 2 towers for operation, wherein one tower is in a feeding adsorption state, the other tower is in a desorption state, all the process steps are adsorption, pressure equalizing and pressure reducing, desorption and pressure equalizing and pressure increasing, and the pressure range of the pressure swing adsorption process is 400-800 KPa, preferably 500-600 KPa.
9. The method of claim 8, wherein a part of desorbed nitrogen is used as working medium gas of the plasma torch, and the other part of gas is exhausted and discharged; and sending the desorbed carbon monoxide to a carbon monoxide storage tank for resource utilization.
10. The method of claim 1, wherein the fireflood tail gas comprises carbon dioxide, nitrogen, water, methane, oxygen, carbon monoxide, hydrogen sulfide, ethane, propane.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202111116368.0A CN113772672B (en) | 2021-09-23 | 2021-09-23 | Fire flooding oil extraction tail gas carbon emission reduction treatment method |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202111116368.0A CN113772672B (en) | 2021-09-23 | 2021-09-23 | Fire flooding oil extraction tail gas carbon emission reduction treatment method |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN113772672A true CN113772672A (en) | 2021-12-10 |
| CN113772672B CN113772672B (en) | 2023-11-07 |
Family
ID=78852895
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202111116368.0A Active CN113772672B (en) | 2021-09-23 | 2021-09-23 | Fire flooding oil extraction tail gas carbon emission reduction treatment method |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN113772672B (en) |
Citations (8)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB1595082A (en) * | 1977-06-17 | 1981-08-05 | Carpenter N L | Method and apparatus for generating gases in a fluid-bearing earth formation |
| ZA8373B (en) * | 1982-01-15 | 1983-10-26 | Air Prod & Chem | Low energy process for separating carbon dioxide and acid gases from a carbonaceous off-gas |
| EP0257493A1 (en) * | 1986-08-22 | 1988-03-02 | Air Products And Chemicals, Inc. | Adsorptive separation of gas mixtures |
| CN103521033A (en) * | 2013-10-19 | 2014-01-22 | 盘锦道博尔石油新技术开发有限公司 | Method for purifying and reclaiming secondary gas in fire flood |
| CN108392958A (en) * | 2018-03-07 | 2018-08-14 | 中国石油天然气股份有限公司 | Treatment system and method for fireflooding high-tail-gas well |
| CN208591716U (en) * | 2018-08-16 | 2019-03-12 | 盘锦道博尔环保科技股份有限公司 | A kind of oilfield fireflood tail gas removing VOCs device |
| CN212327831U (en) * | 2020-05-28 | 2021-01-12 | 大连科林能源工程技术开发有限公司 | Environmental-friendly resourceful treatment system for fireflood tail gas |
| CN113371679A (en) * | 2021-05-27 | 2021-09-10 | 中国矿业大学 | Carbon dioxide-methane plasma high-temperature reforming device and high-temperature reforming method |
-
2021
- 2021-09-23 CN CN202111116368.0A patent/CN113772672B/en active Active
Patent Citations (8)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB1595082A (en) * | 1977-06-17 | 1981-08-05 | Carpenter N L | Method and apparatus for generating gases in a fluid-bearing earth formation |
| ZA8373B (en) * | 1982-01-15 | 1983-10-26 | Air Prod & Chem | Low energy process for separating carbon dioxide and acid gases from a carbonaceous off-gas |
| EP0257493A1 (en) * | 1986-08-22 | 1988-03-02 | Air Products And Chemicals, Inc. | Adsorptive separation of gas mixtures |
| CN103521033A (en) * | 2013-10-19 | 2014-01-22 | 盘锦道博尔石油新技术开发有限公司 | Method for purifying and reclaiming secondary gas in fire flood |
| CN108392958A (en) * | 2018-03-07 | 2018-08-14 | 中国石油天然气股份有限公司 | Treatment system and method for fireflooding high-tail-gas well |
| CN208591716U (en) * | 2018-08-16 | 2019-03-12 | 盘锦道博尔环保科技股份有限公司 | A kind of oilfield fireflood tail gas removing VOCs device |
| CN212327831U (en) * | 2020-05-28 | 2021-01-12 | 大连科林能源工程技术开发有限公司 | Environmental-friendly resourceful treatment system for fireflood tail gas |
| CN113371679A (en) * | 2021-05-27 | 2021-09-10 | 中国矿业大学 | Carbon dioxide-methane plasma high-temperature reforming device and high-temperature reforming method |
Non-Patent Citations (1)
| Title |
|---|
| 李志岩;: "稠油火驱尾气处理工艺技术研究", 化工管理, no. 35, pages 284 * |
Also Published As
| Publication number | Publication date |
|---|---|
| CN113772672B (en) | 2023-11-07 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN101417200B (en) | Carbon dioxide, nitrogen gas recovering method in boiler flue gas | |
| CN102000486B (en) | Method for catching carbon dioxide in flue gas by active sodium carbonate and apparatus thereof | |
| CN107970743B (en) | Method for separating carbon dioxide | |
| WO2008052465A1 (en) | A sintered flue gas wet desulfurizing and dedusting process | |
| CN102068876A (en) | Flue gas desulfurization process | |
| CN103721553A (en) | Method for efficiently removing acid gas sulfide by ammonia process desulfurization technique | |
| CN112915777A (en) | Blast furnace gas dechlorination, desulfurization and purification process | |
| CN104857838A (en) | System and method for flue gas desulfurization through bipolar membrane electrodialysis | |
| CN101092576A (en) | Method for removing acid gases in cracked gas | |
| CN104087354B (en) | A kind of technique utilizing yellow phosphoric tail gas synthetic natural gas | |
| CN102527214A (en) | Method for removing hydrogen sulfide from gas | |
| CN104560223A (en) | Gas desulfurization device and method thereof | |
| CN105126380B (en) | A kind of coking exhaust gas treating method | |
| CN108722161A (en) | A kind of system and method removing hydrogen sulfide in oil field companion, secondary anger | |
| CN105647592A (en) | Recovery system and recovery method of low-order coal pyrolysis oil gas | |
| CN105820846B (en) | A kind of full temperature journey pressure swing adsorption purge method of coke-stove gas benzene-removal naphthalene-removal | |
| CN111575075A (en) | A method for combined desulfurization and decarbonization of biogas with solid waste and waste lye | |
| CN114832584A (en) | CO based on two-phase absorbent rich liquid concentrated phase desorption 2 Trapping system and method | |
| CN106047424B (en) | Coke oven gas hydrogen sulfide gas recovery method and device | |
| CN106890545A (en) | The separating technology and equipment of hydrogen sulfide in a kind of carbon disulphide production tail gas | |
| CN210826085U (en) | Blast furnace gas catalytic desulfurization device | |
| CN215962897U (en) | Carbon emission reduction treatment system for oilfield fireflood tail gas | |
| CN204325296U (en) | A kind of gas desulfurizer | |
| CN113772672B (en) | Fire flooding oil extraction tail gas carbon emission reduction treatment method | |
| CN104984628A (en) | Organic waste gas adsorption recovery process |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |