CN113803049B - Treatment method of oilfield fireflood produced gas - Google Patents
Treatment method of oilfield fireflood produced gas Download PDFInfo
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- CN113803049B CN113803049B CN202010531046.1A CN202010531046A CN113803049B CN 113803049 B CN113803049 B CN 113803049B CN 202010531046 A CN202010531046 A CN 202010531046A CN 113803049 B CN113803049 B CN 113803049B
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- 238000000034 method Methods 0.000 title claims abstract description 31
- 238000000926 separation method Methods 0.000 claims abstract description 46
- 239000007788 liquid Substances 0.000 claims abstract description 35
- 238000004458 analytical method Methods 0.000 claims abstract description 27
- 238000001514 detection method Methods 0.000 claims abstract description 21
- 239000007789 gas Substances 0.000 claims description 173
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 72
- 239000001257 hydrogen Substances 0.000 claims description 42
- 229910052739 hydrogen Inorganic materials 0.000 claims description 42
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 claims description 32
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims description 14
- 150000002431 hydrogen Chemical class 0.000 claims description 11
- 238000007791 dehumidification Methods 0.000 claims description 10
- 239000012528 membrane Substances 0.000 claims description 9
- 238000001179 sorption measurement Methods 0.000 claims description 9
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 claims description 8
- 229910052760 oxygen Inorganic materials 0.000 claims description 8
- 239000001301 oxygen Substances 0.000 claims description 8
- 239000001569 carbon dioxide Substances 0.000 claims description 7
- 229910002092 carbon dioxide Inorganic materials 0.000 claims description 7
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 claims description 5
- 229910052717 sulfur Inorganic materials 0.000 claims description 5
- 239000011593 sulfur Substances 0.000 claims description 5
- 238000001914 filtration Methods 0.000 claims description 4
- 230000006641 stabilisation Effects 0.000 claims description 3
- 238000011105 stabilization Methods 0.000 claims description 3
- 239000000428 dust Substances 0.000 claims description 2
- 238000011084 recovery Methods 0.000 abstract description 10
- 239000003921 oil Substances 0.000 description 18
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 8
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 description 6
- 230000000694 effects Effects 0.000 description 6
- 229910000037 hydrogen sulfide Inorganic materials 0.000 description 6
- 230000008569 process Effects 0.000 description 6
- 238000004064 recycling Methods 0.000 description 6
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 description 5
- 229910002091 carbon monoxide Inorganic materials 0.000 description 4
- 239000010779 crude oil Substances 0.000 description 4
- 229910052757 nitrogen Inorganic materials 0.000 description 4
- 239000000126 substance Substances 0.000 description 4
- 238000010521 absorption reaction Methods 0.000 description 3
- 238000003912 environmental pollution Methods 0.000 description 3
- 238000004868 gas analysis Methods 0.000 description 3
- 238000004519 manufacturing process Methods 0.000 description 3
- 239000000463 material Substances 0.000 description 3
- 238000003860 storage Methods 0.000 description 3
- 239000002699 waste material Substances 0.000 description 3
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 3
- 238000006243 chemical reaction Methods 0.000 description 2
- 238000005265 energy consumption Methods 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 239000000203 mixture Substances 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 239000003345 natural gas Substances 0.000 description 2
- 239000012071 phase Substances 0.000 description 2
- 239000002904 solvent Substances 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 238000010795 Steam Flooding Methods 0.000 description 1
- 238000010793 Steam injection (oil industry) Methods 0.000 description 1
- 239000003463 adsorbent Substances 0.000 description 1
- 150000001335 aliphatic alkanes Chemical class 0.000 description 1
- 238000002485 combustion reaction Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 238000005336 cracking Methods 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 238000007599 discharging Methods 0.000 description 1
- 238000001035 drying Methods 0.000 description 1
- 230000005611 electricity Effects 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 239000003546 flue gas Substances 0.000 description 1
- 239000000295 fuel oil Substances 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- 230000002779 inactivation Effects 0.000 description 1
- 229910052500 inorganic mineral Inorganic materials 0.000 description 1
- 239000007791 liquid phase Substances 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 239000011707 mineral Substances 0.000 description 1
- 239000002120 nanofilm Substances 0.000 description 1
- 238000007254 oxidation reaction Methods 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 239000003209 petroleum derivative Substances 0.000 description 1
- 230000002035 prolonged effect Effects 0.000 description 1
- 238000000746 purification Methods 0.000 description 1
- 230000002441 reversible effect Effects 0.000 description 1
- 238000004062 sedimentation Methods 0.000 description 1
- 230000000087 stabilizing effect Effects 0.000 description 1
- 231100000331 toxic Toxicity 0.000 description 1
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Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/34—Arrangements for separating materials produced by the well
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
- E21B43/243—Combustion in situ
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/34—Arrangements for separating materials produced by the well
- E21B43/40—Separation associated with re-injection of separated materials
Abstract
The invention provides a treatment method of oilfield fireflood produced gas. The treatment method of the oilfield fireflood produced gas comprises the following steps: introducing the produced gas into a gas-liquid separation device; detecting and analyzing the separated produced gas; classifying the produced gas after detection and analysis; the remaining gas is transported and reinjected back to the reservoir. The invention solves the problem of low recovery and utilization rate of the oilfield fireflood produced gas in the prior art.
Description
Technical Field
The invention relates to the technical field of petroleum and natural gas exploration and development, in particular to a treatment method of oilfield fireflood produced gas.
Background
In-situ combustion is an oil extraction method which uses electricity or chemistry to make the temperature of oil layer reach the ignition point of crude oil, and injects air or oxygen into the oil layer to make the crude oil in the oil layer continuously burn. The fireflood process is accompanied with complex heat transfer, mass transfer and physical and chemical changes, and has various exploitation mechanisms such as steam flooding, hot water flooding, flue gas flooding and the like, so that the fireflood process becomes a successor development mode with the most potential of the heavy oil reservoir in the later stage of steam injection development.
Before the ignition of the fireflood is carried out, the early steam huff and puff is needed, the process of cracking and oxidation reaction of the stratum thick oil and injected steam is carried out, and the temperature of the produced liquid is 20-40 ℃; at the same time, a certain mass of gas is produced, the gas produced at this stage is mainly alkane and methane>90% and lower in hydrogen sulfide content. As the ignition drive proceeds, the thick oil, stratum minerals and injected air will produce a large amount of gas, and the methane content of the produced gas<10%, nitrogen content of about 50% to 80%, carbon dioxide content of 10% to 20%, oxygen content of 1% to 2%, hydrogen sulfide content of 100mg/m 3 To 1000mg/m 3 The hydrogen content of partial wells is higher than 5% and is not equal. Because the toxic and harmful gases such as hydrogen sulfide and carbon monoxide are mixed in the produced gas, the environment is polluted by directly discharging the gas, and the gas with recycling value such as methane and hydrogen is also present in the produced gas, the produced gas is recycled, so that additional economic benefits can be generated, but the environmental protection is facilitated.
The current common treatment modes of fireflood produced gas include a chemical absorption method, a pressure swing adsorption method, a membrane separation method and a low-temperature separation method. The chemical absorption method realizes separation by chemical reaction with solvent and regenerates the solvent by the reverse reaction; the pressure swing adsorption method utilizes the different adsorption capacity of the adsorbent for the same gas under different pressures to realize the separation of the gas; the membrane separation technology relies on the difference of the permeability of different gases to different film materials to realize the separation of the gases; the low-temperature separation realizes the liquefaction separation by utilizing the different dew points of different components of the gas. For the separation mode of the produced gas of the oilfield fireflood commonly used at present, the method has certain limitation in engineering application: the chemical absorption method has the problems of large equipment investment, high energy consumption and the like; the pressure swing adsorption method and the membrane separation method have the characteristics of small treatment capacity, easy material inactivation and the like; the low-temperature separation method has the defects of complex post-treatment process, high energy consumption and the like. The traditional produced gas treatment device has single method, usually needs to treat the oilfield produced gas by the process technologies of recovery, drying, purification, liquefaction and the like, can recover a certain amount of light hydrocarbon and natural gas, has larger investment and higher cost, and is not suitable for the disposal requirement of oilfield produced gas reinjection.
From the above, the problem of low recovery and utilization rate of the produced gas of the oilfield fireflood exists in the prior art.
Disclosure of Invention
The invention mainly aims to provide a treatment method of oilfield fireflood produced gas, which aims to solve the problem of low recovery and utilization rate of oilfield fireflood produced gas in the prior art.
In order to achieve the above purpose, the invention provides a treatment method of oilfield fireflood produced gas, which comprises the following steps: introducing the produced gas into a gas-liquid separation device; detecting and analyzing the separated produced gas; classifying the produced gas after detection and analysis; the remaining gas is transported and reinjected back to the reservoir.
Further, the produced gas needs to be dehumidified and dedusted before the separated produced gas is detected and analyzed.
Further, the step of classifying the produced gas after the detection and analysis includes collecting methane, and the step of collecting methane includes: step S10: when the content of methane in the produced gas is higher than 40%, introducing the produced gas into a pressure swing adsorption device for sulfur removal; step S20: introducing the produced gas into a dehumidifying device for dehumidification; step S30: purifying methane after dehumidification; step S40: and recycling the purified methane into a methane storage tank.
Further, the step of classifying and collecting the produced gas after the detection and analysis is completed comprises the step of collecting hydrogen, and the step of collecting hydrogen comprises the following steps: step S100: when the content of hydrogen in the produced gas is higher than 10%, introducing the produced gas into a hydrogen molecular membrane for filtering; step S200: introducing the filtered produced gas into a dehumidifying device for dehumidification; step S300: purifying the dehumidified hydrogen; step S400: and recycling the purified hydrogen into the hydrogen storage tank.
Further, the step of classifying the produced gas after the detection and analysis is completed includes direct reinjection, and the direct reinjection includes: and when the content of carbon dioxide in the produced gas is higher than 10 percent and the contents of methane, hydrogen and oxygen are lower than 5 percent, directly reinjecting the produced gas to the oil reservoir.
Further, passing the produced gas into the gas-liquid separation device comprises: the separated product stream is flowed into a gathering line.
Further, the volume of the gas-liquid separation device is greater than 1000L.
Further, the gas-liquid separation device is a secondary separation.
Further, the pressure stabilization treatment is required to be carried out on the produced gas before the separated produced gas is detected and analyzed, so as to ensure that the pressure is maintained at 0.2MPa.
Further, delivering and reinjecting the residual gas to the reservoir includes: and (5) pressurizing the residual gas.
By applying the technical scheme of the invention, the produced gas of the oilfield fireflood is separated through the gas-liquid separation device, the separated produced gas is detected and analyzed, and the produced gas is classified according to the analysis result, so that methane, hydrogen and the like in the produced gas are respectively recovered and purified, the utilization rate of the produced gas is improved, the environmental pollution is reduced, the residual gas is conveyed and reinjected to an oil reservoir, the recovery ratio of the oil reservoir is improved, the oilfield development effect is improved, and the recycling of the produced gas of the oilfield fireflood is realized.
Drawings
The accompanying drawings, which are included to provide a further understanding of the invention and are incorporated in and constitute a part of this specification, illustrate embodiments of the invention and together with the description serve to explain the invention. In the drawings:
FIG. 1 illustrates a flow chart of a method of treating oilfield fireflood produced gas in one embodiment of the invention; and
FIG. 2 shows a schematic structural view of an oilfield fireflood produced gas treatment device in one embodiment of the invention.
Wherein the above figures include the following reference numerals:
10. a fireflood production well; 20. a first-stage gas-liquid separation device; 30. a secondary gas-liquid separation device; 40. a gas on-line analysis device; 50. a hydrogen molecular membrane; 60. a pressure swing adsorption apparatus; 70. a hydrogen reservoir tank; 80. a methane reservoir tank; 90. a supercharging device; 100. and (5) reinjecting the gas into the well.
Detailed Description
It should be noted that, in the case of no conflict, the embodiments and features in the embodiments may be combined with each other. The invention will be described in detail below with reference to the drawings in connection with embodiments.
It is noted that all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this application belongs unless otherwise indicated.
In the present invention, unless otherwise indicated, terms of orientation such as "upper, lower, top, bottom" are used generally with respect to the orientation shown in the drawings or with respect to the component itself in the vertical, upright or gravitational direction; also, for ease of understanding and description, "inner and outer" refers to inner and outer relative to the profile of each component itself, but the above-mentioned orientation terms are not intended to limit the present invention.
It will be apparent that the embodiments described above are merely some, but not all, embodiments of the invention. All other embodiments, which can be made by those skilled in the art based on the embodiments of the present invention without making any inventive effort, shall fall within the scope of the present invention.
The invention provides a treatment method of oilfield fireflood produced gas, which aims to solve the problem of low recovery and utilization rate of oilfield fireflood produced gas in the prior art.
As shown in fig. 1, the treatment method of the oilfield fireflood produced gas comprises the following steps: introducing the produced gas into a gas-liquid separation device; detecting and analyzing the separated produced gas; classifying the produced gas after detection and analysis; the remaining gas is transported and reinjected back to the reservoir.
The gas-liquid separation device is used for separating the produced gas of the oilfield fireflood, detecting and analyzing the separated produced gas, and classifying the produced gas according to the analysis result, so that methane, hydrogen and the like in the produced gas are respectively recovered and purified, the utilization rate of the produced gas is improved, the environmental pollution is reduced, the residual gas is conveyed and reinjected to an oil reservoir, the recovery ratio of the oil reservoir is improved, the oilfield development effect is improved, and the reuse of the produced gas of the oilfield fireflood is realized.
In this embodiment, delivering and reinjecting the residual gas to the reservoir includes: and (5) pressurizing the residual gas. Specifically, the surplus gas is pressurized by the pressurizing means 90. And the power for reinjection into the oil reservoir is provided for the residual gas by carrying out supercharging treatment on the residual gas, so that the reinjection effect is better.
As shown in fig. 2, the produced gas of the fireflood in the oilfield enters the gas-liquid separation device to perform gas-liquid separation, and the separated produced gas is detected and analyzed by the gas on-line analysis device 40, and then classified according to the analysis result, and the produced gas is classified into three types. The first kind of produced gas enters the pressure swing adsorption device 60 for treatment, the second kind of produced gas enters the hydrogen molecular membrane 50 for treatment, the third kind of produced gas is directly reinjected into the gas reinjection well 100 through the pressurizing device 90, and finally, the residual gas is reinjected into the gas reinjection well 100 through the pressurizing device 90 and finally reinjected into the oil reservoir.
Specifically, the supercharging device 90 in this embodiment is a booster pump.
Specifically, the step of introducing the produced gas into the gas-liquid separation device comprises the steps of: the separated product stream is flowed into a gathering line. Thus, the crude oil in the separated produced liquid is collected, the recovery ratio of the crude oil is improved, and the produced liquid is prevented from entering a subsequent device to influence the recycling of the produced gas.
As shown in fig. 2, the gas-liquid separation device is a secondary separation, and specifically, the gas-liquid separation device includes a primary gas-liquid separation device 20 and a secondary gas-liquid separation device 30. Through the second-stage separation, the produced gas produced by the fireflood production well 10 can be subjected to gas-liquid separation more thoroughly, so that the produced liquid is separated and collected to the greatest extent, the recovery ratio is improved, the resource waste is prevented, and the produced liquid is prevented from entering a subsequent device to influence the recycling of the produced gas.
In the present embodiment, the volumes of the primary gas-liquid separation device 20 and the secondary gas-liquid separation device 30 are both larger than 1000L. Thus, the gas-liquid separation device has enough capacity, so that the gas-liquid separation effect is better.
In this embodiment, the produced gas after separation needs to be dehumidified and dedusted before being subjected to detection and analysis. By performing the dehumidification and dust removal treatment on the produced gas, the accuracy of the gas analysis data of the gas online analysis device 40 is ensured, and the damage of the produced gas to the gas online analysis device 40 can be reduced.
The gas online analysis device 40 in this embodiment has a function of detecting seven gas components, such as carbon dioxide, oxygen, hydrogen sulfide, hydrogen, carbon monoxide, nitrogen, and methane.
In this embodiment, since the pressure of the produced gas is unstable, the produced gas needs to be subjected to pressure stabilizing treatment before the separated produced gas is subjected to detection and analysis, so as to ensure that the pressure is maintained at 0.2MPa. The stabilization of the pressure of the produced gas also ensures the accuracy of the gas analysis data of the gas on-line analysis device 40.
In this embodiment, classifying the produced gas after the detection analysis is completed includes collecting methane. The step of collecting methane comprises: step S10: when the content of methane in the produced gas is higher than 40%, introducing the produced gas into the pressure swing adsorption device 60 for sulfur removal; step S20: the produced gas is introduced into a dehumidifying device (not shown in the figure) for dehumidification; step S30: purifying methane after dehumidification; step S40: the purified methane is recovered into the methane reservoir tank 80. The produced gas is classified, so that the methane in the produced gas is collected and purified, the methane in the produced gas is recycled, resource waste is avoided, and pollution of the methane to the environment is also prevented. In addition, through carrying out the sulfur removal treatment to the produced gas, the corrosion of the produced gas to the transportation pipeline is reduced, and the service life of the transportation pipeline of the produced gas is prolonged.
In this embodiment, classifying and collecting the produced gas after the detection and analysis are completed includes collecting hydrogen. The step of collecting hydrogen gas includes: step S100: when the content of hydrogen in the produced gas is higher than 10%, the produced gas is introduced into the hydrogen molecular membrane 50 for filtration; step S200: introducing the filtered produced gas into a dehumidifying device for dehumidification; step S300: purifying the dehumidified hydrogen; step S400: the purified hydrogen is recovered into the hydrogen reservoir tank 70. By classifying the produced gas, the hydrogen in the produced gas is collected and purified, so that the hydrogen in the produced gas is recycled, and resource waste is avoided.
Specifically, the hydrogen molecular film 50 in the present embodiment is made of a polymeric material.
In this embodiment, classifying the produced gas after the detection and analysis is completed includes direct reinjection. The step of direct reinjection comprises: and when the content of carbon dioxide in the produced gas is higher than 10 percent and the contents of methane, hydrogen and oxygen are lower than 5 percent, directly reinjecting the produced gas to the oil reservoir. Specifically, produced gas is reinjected through pressurization device 90 to gas reinjection well 100 and ultimately back to the reservoir.
In one particular embodiment, the output of the fireflood well 10 of the oilfield is a three-phase mixture of oil, gas, and water, the output is in the form of a foamed oil, and the liquid production is about 20 tons/day, with a water content of about 80%. The output is passed through a gas-liquid separation device, and the gas phase and the liquid phase in the output are subjected to secondary separation by utilizing the principle of physical sedimentation and rotational flow.
After gas-liquid separation, the produced gas is detected and analyzed, and the process is automatically transferred to the next flow according to the result of gas analysis. In a period of time, the detection result of the components of the produced gas is that the content of carbon dioxide is 12.4%, the content of oxygen is 0.2%, the content of carbon monoxide is 0%, the content of nitrogen is 82.2%, the content of hydrogen sulfide is 10ppm, the content of methane is 3.7%, and the content of hydrogen is 1.5%. From the gas detection results, it is seen that direct reinjection is required for the third type of produced gas. Produced gas is reinjected through the pressurizing device 90 to the gas reinjection well 100 and ultimately to the reservoir.
In another time period, the detection result of the composition of the produced gas is that the content of carbon dioxide is 9.3%, the content of oxygen is 0.3%, the content of carbon monoxide is 0%, the content of nitrogen is 65.2%, the content of hydrogen sulfide is 8ppm, the content of methane is 3.7%, and the content of hydrogen is 21.5%. The second type of produced gas is seen from the gas detection results, and the hydrogen needs to be collected. The produced gas is introduced into the hydrogen molecular membrane 50 for filtration, the filtered produced gas is introduced into the dehumidifying device for dehumidification, the dehumidified hydrogen is purified, and finally the purified hydrogen is recovered into the hydrogen storage tank 70.
From the above description, it can be seen that the above embodiments of the present invention achieve the following technical effects: the gas-liquid separation device is used for separating the produced gas of the oilfield fireflood, detecting and analyzing the separated produced gas, and classifying the produced gas according to the analysis result, so that methane, hydrogen and the like in the produced gas are respectively recovered and purified, the utilization rate of the produced gas is improved, the environmental pollution is reduced, the residual gas is conveyed and reinjected to an oil reservoir, the recovery ratio of the oil reservoir is improved, the oilfield development effect is improved, and the reuse of the produced gas of the oilfield fireflood is realized.
It is noted that the terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting of example embodiments in accordance with the present application. As used herein, the singular is also intended to include the plural unless the context clearly indicates otherwise, and furthermore, it is to be understood that the terms "comprises" and/or "comprising" when used in this specification are taken to specify the presence of stated features, steps, operations, devices, components, and/or combinations thereof.
It should be noted that the terms "first," "second," and the like in the description and claims of the present application and the above figures are used for distinguishing between similar objects and not necessarily for describing a particular sequential or chronological order. It is to be understood that the data so used may be interchanged where appropriate such that embodiments of the present application described herein may be implemented in sequences other than those illustrated or described herein.
The above is only a preferred embodiment of the present invention, and is not intended to limit the present invention, but various modifications and variations can be made to the present invention by those skilled in the art. Any modification, equivalent replacement, improvement, etc. made within the spirit and principle of the present invention should be included in the protection scope of the present invention.
Claims (7)
1. A method for treating oilfield fireflood produced gas, comprising:
introducing the produced gas into a gas-liquid separation device;
detecting and analyzing the separated produced gas;
classifying the produced gas after detection and analysis are completed;
delivering and reinjecting the remaining gas to the reservoir;
the step of classifying the produced gas after the detection and analysis is completed comprises the step of collecting methane, wherein the step of collecting methane comprises the following steps:
step S10: when the content of methane in the produced gas is higher than 40%, introducing the produced gas into a pressure swing adsorption device (60) for sulfur removal;
step S20: introducing the output gas after sulfur removal into a dehumidifying device to dehumidify;
step S30: purifying methane after dehumidification;
step S40: recovering the purified methane into a methane reservoir tank (80);
the step of classifying and collecting the produced gas after the detection and analysis is completed comprises the step of collecting hydrogen, wherein the step of collecting the hydrogen comprises the following steps:
step S100: when the content of hydrogen in the produced gas is higher than 10%, introducing the produced gas into a hydrogen molecular membrane (50) for filtering;
step S200: introducing the filtered produced gas into a dehumidifying device to dehumidify;
step S300: purifying the dehumidified hydrogen;
step S400: recovering the purified hydrogen into a hydrogen reservoir tank (70);
the step of classifying the produced gas after the detection and analysis is completed comprises direct reinjection, wherein the step of direct reinjection comprises the following steps:
and when the content of carbon dioxide in the produced gas is higher than 10 percent and the contents of methane, hydrogen and oxygen are lower than 5 percent, directly reinjecting the produced gas to the oil reservoir.
2. The method for treating oilfield fireflood produced gas according to claim 1, wherein the separated produced gas is subjected to dehumidification and dust removal prior to detection and analysis.
3. The method for treating oilfield fireflood produced gas as claimed in claim 1, wherein said passing the produced gas to a gas-liquid separation device comprises: the separated product stream is flowed into a gathering line.
4. The method for treating oilfield fireflood gas as claimed in claim 1, wherein the volume of the gas-liquid separation device is greater than 1000L.
5. The method for treating oilfield fireflood gas as claimed in claim 1, wherein said gas-liquid separation device is a secondary separation.
6. The method for treating oilfield fireflood produced gas according to claim 1, wherein the separated produced gas is subjected to pressure stabilization treatment before being subjected to detection and analysis to ensure that the pressure is maintained at 0.2MPa.
7. The method of treating oilfield fireflood gas as defined in claim 1, wherein said delivering and reinjecting the residual gas into the reservoir comprises: and carrying out pressurization treatment on the residual gas.
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| 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 |
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