CN113278454A

CN113278454A - Local natural gas desulfurization method

Info

Publication number: CN113278454A
Application number: CN202110287917.4A
Authority: CN
Inventors: 李晟贤
Original assignee: Individual
Current assignee: Individual
Priority date: 2021-03-17
Filing date: 2021-03-17
Publication date: 2021-08-20

Abstract

The invention discloses a local natural gas desulfurization method, which comprises the following steps: 1) firstly, separating a gas-liquid mixture produced by a gas well into natural gas and produced liquid, and then enabling the produced liquid to enter a sewage treatment plant for further treatment; 2) adding oxidant liquid with the content of more than 0.001% into the separated natural gas to oxidize hydrogen sulfide and/or odorous substances in the natural gas to form a sulfur-containing solid-liquid mixture; 3) then the solid-liquid mixture is separated from the natural gas, and the natural gas after the solid-liquid mixture is separated is led into an inlet pipeline or/and an inter-station pipeline of a purification device so as to be further processed in the purification device or/and a natural gas purification treatment plant. The invention can lead the sulfur-containing gas well to utilize the existing gas collecting stations and inter-station pipelines which are conventionally designed to produce, can greatly reduce the fixed investment of the gas field, and is particularly suitable for the gas field or block with the coexisting sulfur-containing gas well and sulfur-free gas well; the method has the advantages of easy implementation, safety, reliability, wide application, easy popularization and the like.

Description

Local natural gas desulfurization method

Technical Field

The invention relates to the field of natural gas production, in particular to a local natural gas desulfurization method.

Background

The national standard GB17820-2018 stipulates that the concentration of hydrogen sulfide in natural gas should be less than or equal to 20mg/m³However, the concentration of hydrogen sulfide in natural gas produced by domestic natural gas wells (gas wells for short) is often higher than 20mg/m³. Taking a plain gas field as an example, the concentration of hydrogen sulfide in natural gas produced by a gas well is generally as high as 100g/m³(i.e., 100000 mg/m)³) Above, some gas wells reach as high as 260g/m³。

Known from the knowledge in the art: hydrogen sulfide is an acute highly toxic malodorous gas, and is dissolved in water to form hydrogen sulfuric acid; inhalation of small amounts of high concentrations of hydrogen sulfide can be fatal in a short time, and low concentrations of hydrogen sulfide have effects on the eyes, respiratory system, and central nervous system.

Therefore, natural gas from domestic gas wells is generally treated and produced by the following desulfurization (also called desulfurization) method.

Firstly, a centralized desulfurization method: the method can be further divided into two categories. One of them, as shown in fig. 1, can be summarized as: natural gas (generally containing a certain amount of water, oil, chemical agents and the like) produced by a gas well 100 enters a gas gathering station 103 through a valve 101 and a gas gathering pipeline 102 and is separated into natural gas and produced liquid; the natural gas separated from the gas collecting station 103 enters a natural gas purification treatment plant 105 through an inter-station pipeline 104 for desulfurization, dew point reduction and other treatment, and enters an external transmission pipeline 106 after reaching the standard; produced liquid separated from the gas collecting station 103 enters a sewage treatment plant 108 through a produced liquid pipeline 107 for oil-water separation, sewage flocculation and other treatment, and sewage reaching the standard enters a reinjection station 110 through a sewage pipeline 109 for pressurization and then is reinjected into the stratum through a water injection pipeline 110 and a water injection well 112.

Another aspect of the method, as shown in fig. 2, can be summarized as: natural gas produced by a gas well 100 enters a gas gathering station 103 through a valve 101 and a gas gathering pipeline 102 and is separated into natural gas and produced liquid; the natural gas separated from the gas gathering station 103 enters a natural gas purification treatment plant 105 through an inter-station pipeline 104 for purification treatment such as desulfurization and dew point reduction, and enters an external transmission pipeline 106 after reaching the standard; the produced liquid separated from the gas collecting station 103 is firstly loaded into the truck tank 201 through the loading pipeline 200, then is transported to the sewage treatment plant 108 by the truck tank 201, enters the sewage treatment plant 108 through the unloading pipeline 202 for oil-water separation, sewage flocculation and other treatments, and the sewage reaching the standard enters the reinjection station 110 through the sewage pipeline 109 for pressurization and then is reinjected into the stratum through the water injection pipeline 110 and the water injection well 112.

Known from the knowledge in the art: taking an extended gas field as an example, the gas field is provided with a plurality of gas collecting stations and 1 sewage treatment plant, the distance from the gas collecting stations to the sewage treatment plant is generally 50-150 kilometers, and the farthest distance is even more than 200 kilometers; the natural gas produced by 5-10 gas wells is collected by 1 gas gathering station generally, the average daily produced liquid of 1 well is less than 0, square ton/day, and the average daily produced liquid of 1 gas gathering station is less than 2 square/day, so that the mode of transporting the produced liquid to a sewage treatment plant by a truck tank car is obviously more economic than the mode of transporting the produced liquid by a produced liquid pipeline; at present, the method of truck tank truck haulage is adopted to prolong the gas field, and produced liquid from a gas gathering station is hauled to a sewage treatment plant for centralized treatment.

The method has the following defects:

1. the method enables the whole gas field ground production system to adopt a sulfur-resistant design, which can lead to the constant investment, the operating cost and the gas production cost of the gas field (or block) ground production system to be high or even multiplied, further leads to the great reduction of the development benefit of the gas field (or block), and even leads a plurality of domestic low-permeability gas fields (or blocks) and shale gas fields with abundant reserves to lose industrial development value.

Known from the knowledge in the art: as shown in fig. 1 and 2, when the centralized desulfurization method is used, hydrogen sulfide contained in natural gas can only be removed in the natural gas purification treatment plant 105, while natural gas in the valve 101, the gas collecting pipeline 102, the gas collecting station 103 and the inter-station pipeline 104 contains hydrogen sulfide, and sewage in the produced liquid pipeline 107 also contains hydrogen sulfide.

Known from the knowledge in the art: according to the standard regulations of GB/T20972, metallic material requirement for resisting sulfide stress cracking and stress corrosion cracking of natural gas ground facilities SY/T0599, steel chemical container material selection regulation HG/T20581-2011 and the like, the basic design requirements of each gas field in China on the ground production system are as follows: when the content of hydrogen sulfide in the gas collecting pipeline 102 is more than 13ppm, a sulfur-resistant design is adopted; when the content of hydrogen sulfide in the pipeline 104 between stations is more than 55ppm, a sulfur-resistant design is adopted; sulfur resistant designs should be used when the hydrogen sulfide content in the yard equipment (including but not limited to the gas station 103, production fluid line 107) is > 55 ppm.

Known from the knowledge in the art: after the sulfur-resistant design is adopted, the pipeline equipment must be made of sulfur-resistant special steel or stainless steel, so the manufacturing cost and the operation cost of the ground production system adopting the sulfur-resistant design are far higher than those of the conventional design, and the fixed investment of the sulfur-resistant ground production system of a medium-sized gas field (or block) is up to billions of yuan after the sulfur-resistant design is adopted; as shown in fig. 1 and 2, the minimum design pressure of the gas collecting pipeline 102 is 6.4MPa, the pipe diameter is generally DN 50-DN 150, the length can reach dozens of kilometers, and the fixed investment of the sulfur-resistant design is extremely large; a plurality of containers and devices with the lowest design pressure of 6.4MPa are arranged in the gas gathering station 103, the fixed investment of the conventional design is about 1000 ten thousand yuan, but the fixed investment of the sulfur-resistant design is up to thousands of thousand yuan; the lowest design pressure of the interstation pipeline 104 is 6.4MPa, the pipe diameter is generally DN 100-DN 300, the pipe diameter is generally 10-50 kilometers, and the fixed investment after the sulfur-resistant design is adopted is extremely high.

Known from the knowledge in the art: the selling price of the special steel and the stainless steel is far higher than that of the common steel.

2. The method can not lead the sulfur-containing gas reservoir block and the sulfur-containing gas well to be produced by utilizing the existing established and operated ground production system with the conventional design, and can not improve the development benefits of the separate production of the sulfur-containing gas reservoir and the sulfur-free gas reservoir; therefore, the method cannot be used for the same field (or block) having both a sour gas well (or sour gas layer) and a sweet gas well (or sweet gas layer), cannot be used for a gas well for producing a sour gas layer and a sweet gas layer separately, and cannot reduce the production cost of the sour gas reservoir.

Known from the knowledge in the art: domestic gas fields (or blocks) commonly have sulfur-containing gas wells and sulfur-free gas wells at the same time, are generally developed by adopting a separate mining method for improving the development benefit and reducing the mining cost, and preferentially develop a sulfur-free gas layer by using a conventionally designed ground production system; the ground production system for developing the sulfur-free gas layer in China does not adopt a sulfur-resistant design, is mainly built by common steel, and can greatly reduce the mining cost of the sulfur-free gas layer; the ground production systems for developing the sulfur-containing gas layer are all designed in a sulfur-resistant mode and mainly built by sulfur-resistant special steel or stainless steel, and when the system is used for producing the sulfur-free gas well, the exploitation cost of the sulfur-free gas layer is greatly increased.

It is known from the calculation of the knowledge in the field that: after natural gas produced by a sulfur-containing gas well enters an existing established and operated ground production system with a conventional design, the sulfur content of the ground production system exceeds the standard, so that the ground production system has serious problems of special corrosion, hydrogen embrittlement and the like of hydrogen sulfide, and even the ground production system is cracked and scrapped and serious casualty accidents occur in serious cases.

Take a cattle field as an example.

The gas field belongs to a low-permeability gas field and consists of an upper part and a lower part which have the same geographic position; wherein the upper gas reservoir is a sulfur-free gas layer, the content of hydrogen sulfide in natural gas produced by the established gas well is less than 13ppm, and the natural gas is generally regarded as a sulfur-free gas well; the Ordovician gas reservoir (also called as a lower ancient gas field) at the lower part belongs to a sulfur-containing gas layer, the built gas well belongs to a sulfur-containing gas well, the content of hydrogen sulfide in natural gas produced by the gas well is generally 100-3000 ppm, and the content of hydrogen sulfide in part of the gas well is even more than 3000 ppm.

In order to improve development benefit and reduce exploitation cost, the gas field adopts respective exploitation methods to develop a sulfur-containing gas layer and a sulfur-free gas layer, preferentially exploits an upper gas reservoir with the hydrogen sulfide content less than 13ppm, and preferentially builds a ground production system only suitable for the hydrogen sulfide content less than 13ppm, wherein the ground production system comprises more than 70 gas gathering stations (which govern 3-50 gas wells, etc.), more than 1600 sulfur-free gas wells, corresponding gas gathering pipelines, inter-station pipelines, etc.

At present, more than 1600 sulfur-free gas wells are built in the gas field, wherein most of the gas wells are mined for more than ten years, some gas wells are mined for more than 15 years, and the gas production capacity of a single well is generally low; and only a few 30 mouth sulfur gas wells are built and used for carrying out production tests, and the other gas wells are not produced, so that the gas production capacity of a single well is generally high.

Known from the knowledge in the art: when the sulfur-containing gas well of the gas field is produced by utilizing the existing established ground production system, natural gas produced by the sulfur-containing gas well is mixed with natural gas produced by a sulfur-free gas well in a gas gathering station, and then enters an inter-station pipeline and the like; the calculation shows that: according to the same gas production amount, after the natural gas produced by 1 sulfur-containing gas well with the hydrogen sulfide content of 100ppm and the natural gas produced by 6 sulfur-free gas wells with the hydrogen sulfide content of 0ppm are uniformly mixed, the hydrogen sulfide content is more than 13ppm, so that the sulfur content of the existing ground production systems which are preferentially built, such as gas field gas gathering stations, inter-station pipelines and the like, exceeds the standard; the same calculations indicate that: after natural gas produced by 1 sulfur-containing gas well with the hydrogen sulfide content of 700ppm and natural gas produced by 52 sulfur-free gas wells with the hydrogen sulfide content of 0ppm are uniformly mixed, the hydrogen sulfide content is more than 13ppm, and the sulfur content of the existing ground production systems which are preferentially built, such as a gas field gas gathering station, an inter-station pipeline and the like, exceeds the standard; further calculations show that: after the natural gas produced by 7 sulfur-containing gas wells with 3000ppm of hydrogen sulfide content and the natural gas produced by 52 sulfur-free gas wells with 0ppm of hydrogen sulfide content are uniformly mixed, the hydrogen sulfide content is more than 13ppm, so that the sulfur content of all the existing ground production systems which are preferentially built in the gas field exceeds the standard; thus, sour wells of a large cattle field cannot be produced using existing, conventionally designed, surface production systems that have been built to operate.

Known from the knowledge in the art: although the centralized desulfurization method can solve the development and production problems of the sulfur-containing gas layer and the gas well of the gas field in the cattle field, billions of yuan is needed to be additionally built, and the gas field is enabled to have two sets of ground production systems in the same area at the same time, so that the sulfur-containing gas reservoir and the sulfur-free gas reservoir of the gas field are meaningless in layered mining, the development cost is greatly increased, and even the sulfur-containing gas reservoir of the gas field loses the industrial development value.

Known from the knowledge in the art: the development benefit of domestic low-permeability gas fields is generally poor due to the restriction of geological conditions; the cost for developing a sulfur-free gas reservoir block by using a ground production system built by common steel in the existing cattle field is very high, and the economic benefit is low; if the gas field is additionally constructed with a sulfur-resistant ground production system to develop the sulfur-containing gas reservoir block, the development benefit of the sulfur-containing gas reservoir block is negative, and the development value is lost.

3. The method can be used for producing natural gas by opening the well after the whole ground production system is completely built, so that the development progress of the gas field is slow, and the development benefit is reduced.

Known from the knowledge in the art: the sulfur-free gas well can be used for single-well production, the produced natural gas can be directly prepared into CNG and LNG at a well site for outward transportation and export sales without entering a ground production system; the sulfur-containing gas well must enter a ground production system for desulfurization and other treatments; at present, no successful precedent exists in China that sulfur-containing gas wells are not put into a ground production system for desulfurization treatment or CNG and LNG are directly prepared at well sites for outward transportation and export sale.

4. The manner in which the produced fluid is transported to the sewage treatment plant 108 by the truck tank 201 as shown in figure 2 cannot be used for sour gas wells.

Known from the knowledge in the art: the natural gas production requirement and the environmental protection requirement both clearly stipulate that the produced liquid must be transported and treated in a sealed way, and hydrogen sulfide in the produced liquid is forbidden to enter the atmospheric environment; the produced liquid of the sulfur-containing gas well is easy to volatilize a large amount of hydrogen sulfide; when the produced liquid containing hydrogen sulfide is loaded, unloaded and transported by the tank truck 201, a large amount of hydrogen sulfide is inevitably emitted into the air, so that the human health is harmed, and even casualty accidents are caused in serious cases.

Secondly, injecting an oxidation type desulfurizer at the well head for desulfurization: the method is characterized in that an oxidation-type sulfur removal agent which is in a liquid state at normal temperature and normal pressure is added into a shaft or a wellhead pipeline, and the oxidation-type sulfur removal agent is used for oxidizing hydrogen sulfide in natural gas into elemental sulfur, so that the problems of special corrosion and hydrogen brittleness of the hydrogen sulfide are solved. The method has the following defects:

1. the method can generate solid sulfur particles in a natural gas shaft or a wellhead pipeline, so that sulfur scale is formed and the shaft and the pipeline are blocked.

Known from the knowledge in the art: the elemental sulfur, namely sulfur, is insoluble in water, does not generate chemical reaction with steel in a natural gas pipeline, and does not generate the problem of hydrogen embrittlement.

Take a cattle field as an example.

The field tests carried out in this field showed that: the tested oxidation type desulfurizing agent has a pH value less than 2 and is strongly acidic; the content of hydrogen sulfide in natural gas produced by a tested sulfur-containing gas well is more than 400ppm, the produced liquid is acidic, and a gas collection pipeline of an oil pipe does not scale before an oxidized sulfur removal agent is injected into an oil pipe outlet; after the oxidized sulfur removal agent is continuously injected at the outlet of the oil pipe, although the content of hydrogen sulfide in natural gas can be reduced to below 13ppm, the gas collection pipeline has the problems of rapid scaling and blockage; further field tests showed that: when the oxidized desulfurizing agent is continuously injected at the outlet of the oil pipe, the gas collecting pipeline of DN50 is blocked by scale within 30 days, so that the tested sulfur-containing gas well cannot produce and the gas collecting pipeline is completely scrapped; further experimental tests show that: the scale blocking the gas collecting pipeline mainly comprises scale forming ions such as sulfur, calcium, magnesium, iron and the like, wherein the content of the sulfur exceeds 20 percent.

2. The iron oxidation type sulfur removal agent used in the method mainly comprises iron ions, and after entering a ground production system through a shaft or a wellhead pipeline, iron scale is further formed to block the pipeline and equipment of the ground production system.

Take a cattle field as an example.

The field tests carried out in this field showed that: the tested iron oxidation type desulfurizing agent is ferric ion complex aqueous solution, and the iron content is more than 30 percent; before the iron oxidation type sulfur removal agent is injected into the outlet of the oil pipe, the heat exchanger of the ground production system slowly scales, and the iron content of the scale is lower than 2%; after the iron oxidation type desulfurizing agent is continuously injected into the outlet of the oil pipe, the heat exchanger has the problem of rapid scaling, and the content of the scaled iron exceeds 20 percent.

Known from the knowledge in the art: the iron content in the gas field produced liquid is generally not more than 30mg/L, the calcium and magnesium content is generally more than 1000mg/L, and the iron content is less than 3 percent of the calcium and magnesium content; the iron content of the scale formed by the calcium magnesium iron scale forming ions in the production fluid will generally not exceed 3%.

Thirdly, a wellhead filling alkaline desulfurizer desulfurization method: the method is characterized in that an alkaline sulfur removal agent which is liquid at normal temperature and normal pressure is added into a shaft or a wellhead pipeline, and the alkaline sulfur removal agent absorbs hydrogen sulfide in natural gas or reacts with the hydrogen sulfide to form water-soluble sulfide, so that the problems of special corrosion and hydrogen brittleness of the hydrogen sulfide are solved. The method has the following defects: the alkaline desulfurizing agent is alkaline, and the alkalinity is enhanced after dilution and hydrolysis in the produced liquid, so that the alkaline desulfurizing agent can form precipitate with scaling ions such as calcium, magnesium, iron and the like in the produced liquid to scale in pipeline equipment.

Known from the knowledge in the art: hydrogen sulfide is an acidic gas, which dissolves in water to form hydrogen sulfuric acid, which can chemically react with alkaline liquid.

Take a cattle field as an example.

The field tests carried out in this field showed that: the tested alkaline desulfurizing agent has a pH value of more than 8, and the pH value of more than 9.5 after the alkaline desulfurizing agent is diluted by distilled water to the concentration of 10 percent; the 10% alkaline desulfurizing agent is added into the calcium chloride and magnesium chloride water solution to produce precipitate, and the 0% alkaline desulfurizing agent is added into the produced liquid of the gas field to produce precipitate.

Fourthly, dry desulfurization: the method is to remove hydrogen sulfide in the natural gas by using the redox reaction of a solid desulfurizer and the hydrogen sulfide, or remove the hydrogen sulfide in the natural gas by using the catalytic action of the solid desulfurizer to make oxygen and the hydrogen sulfide perform the redox reaction, or adsorb the hydrogen sulfide in the natural gas by using the solid desulfurizer; thereby solving the problems of corrosion and hydrogen embrittlement peculiar to hydrogen sulfide. The method has the following defects:

1. the solid desulfurizer used by the method needs to be prepared into a specific shape and stacked or piled in a closed container for static use, cannot be used in a fluidized bed form, needs to be replaced periodically, and has high labor intensity and high danger in the process of replacing the solid desulfurizer.

Known from the knowledge in the art: the activated carbon type desulfurizer, the molecular sieve type desulfurizer, the iron oxide type desulfurizer, the zinc oxide type desulfurizer and the manganese oxide type desulfurizer are all common solid desulfurizers at present; taking the iron oxide type desulfurizer as an example, the desulfurization mechanism is as follows: reacting the ferric oxide with hydrogen sulfide to generate ferric sulfide, ferrous sulfide and sulfur; therefore, when the reaction of the iron oxide in the iron oxide type desulfurizer is finished, the iron oxide type desulfurizer needs to be replaced by new iron oxide type desulfurizer; when the iron oxide type desulfurizer is replaced, the closed container is opened, the iron oxide type desulfurizer is taken out of the closed container by manpower or special machinery, then the new iron oxide type desulfurizer is put into the container and stacked or stacked according to a special mode, and then the closed container is closed; the iron oxide type desulfurizer after absorbing the hydrogen sulfide is placed in the air to easily react with oxygen and spontaneously combust.

2. The replaced solid desulfurizer can not be regenerated in natural gas production places such as well sites, gas gathering stations and the like, and must be sent to a specific hazardous waste treatment site for regeneration or other harmless special treatment, so that the desulfurization cost of the natural gas is huge.

Known from the knowledge in the art: the iron oxide type desulfurizer after absorbing hydrogen sulfide belongs to dangerous solid waste, is extremely easy to spontaneously combust when being placed in air, is easy to generate flammable and explosive accidents when being regenerated in natural gas production places, and generates pollutants such as sulfur dioxide and the like during combustion.

In a word, the methods have defects, and the requirements of natural gas production are not met.

Disclosure of Invention

The invention has the following local formula: also called gas collection station type, small station type; the gas collection station can be in the gas collection station or near the gas collection station, and can also be a gathering position and a gathering pipe position of a natural gas conveying pipeline produced by more than 2 gas wells.

"desulfurization" in the present invention: also known as sulfur removal; it may refer to the removal of hydrogen sulfide, or the removal of hydrogen sulfide, mercaptan, thioether, etc., or the removal of malodorous pollutant specified in GB14554-1993 discharge Standard for malodorous pollutant.

"sour gas wells" in the present invention: sometimes referred to as gas well, it is common to refer to gas well producing natural gas containing hydrogen sulfide, mercaptans, sulfides, etc.

The invention relates to a malodorous gas: it refers to volatile substances of malodorous pollutants specified in the emission Standard of malodorous pollutants, and may also refer to toxic or odorous and unpleasant gases.

The term "natural gas" in the context of the present invention means: natural gas flowing from a gas reservoir into a gas well, or combustible gas produced from a subterranean formation, including natural gas formed by the breakdown of subterranean natural gas hydrates (e.g., combustible ice); natural gas is called as field gas, natural gas produced from oil field is called as oil field gas (also called as associated gas), natural gas produced from coal bed is called as coal bed gas and coal gas, and natural gas produced from shale is called as shale gas; refers to a mixture of hydrocarbon and non-hydrocarbon gases that are naturally trapped in subterranean formations; generally, the water-based oil-gas well drilling fluid contains liquid substances such as water, oil, gas production aids, fracturing fluid and the like, and gaseous substances such as steam, hydrogen sulfide, carbon dioxide, mercaptan, thioether and the like, and some substances contain no water.

The "gas reservoir layer" in the present invention means: the gas layer or reservoir layer is a stratum with natural gas.

"gas collection line" in the present invention: the natural gas pipeline is also called a gas production pipeline or a mine field gathering pipeline and refers to a natural gas pipeline between a gas well and a gas gathering station; some gas collecting pipelines only convey natural gas of 1 gas well, and some gas collecting pipelines collect and convey natural gas of more than 2 gas wells; the length of the gas collecting pipeline is generally 300-20000 meters.

"gas gathering station" in the present invention: the system is also called a gas collection metering station or a metering station, commonly called a small station, generally governs 2-50 gas wells, namely, natural gas produced by 2-50 gas wells is collected, mixed, treated, conveyed and managed in the gas collection station; the specific production function (or procedure links) is different for different gas fields (or blocks), and generally has the functions of gas-liquid separation (commonly called liquid separation), gas yield metering and water yield metering; some also have the functions of oil-water separation, storage and transportation; some of the natural gas dehydration products also have the functions of heating (namely, increasing the temperature of the natural gas), throttling and depressurizing (namely, reducing the pressure of the natural gas in a throttling mode), dehydrating (namely, removing water in the natural gas), and reducing dew point (namely, reducing the dew point of the natural gas, which is commonly called drying); some also have a boosting (i.e., increasing natural gas pressure) function.

The "interstation pipeline" in the present invention means: the natural gas pipeline is also called gathering pipeline and is used between a gas gathering station and a natural gas purification treatment plant; typically as long as 2-50 km.

The invention relates to a ground production system: the ground system is also called ground engineering or ground production system and ground production process.

"export line" in the present invention: the long-distance pipeline refers to a storage and transportation pipeline for natural gas leaving a gas field to a user, and generally has a large pipe diameter and a large gas transmission amount, and the length is generally 5-3000 kilometers.

The invention relates to a natural gas purification treatment plant: the natural gas purification treatment plant is also called a natural gas purification treatment station or a natural gas purification device with small scale, which is called a purification plant (plant) or a treatment plant (plant) for short, and is commonly called a centralized treatment station or a large station; generally takes charge of the centralized purification treatment of the natural gas produced by 1 gas field or 1 gas field block; there are also processes for the production fluids transported or piped from the gathering station by vehicles.

"purification" in the present invention means: the natural gas produced by the gas well is subjected to any one or more than two treatment processes of desulfurization, decarburization, dehydration, dealkylation, dew point reduction and the like.

The 'produced liquid' in the invention: the main components of the liquid substances (including various liquids condensed and separated from natural gas) produced from the gas well are water, generally including oil substances, fracturing fluid, gas production aids and the like; usually, the mineralization degree is very high, and the minerals contain a large amount of calcium ions, magnesium ions and iron ions.

The gas production auxiliary agent in the invention: refers to a functional chemical agent used in the production process of natural gas exploitation.

The "sulfur scale" in the present invention means: scale formed by mixing sulfur and calcium, magnesium and iron plasma is easy to deposit on the pipe wall.

The "iron scale" in the present invention means: scale with higher iron content.

The term "separate mining" in the present invention means: the term "separate mining" is used for short.

The "sulfur-resistant design" in the present invention means: the material of the pipeline equipment used in the gas field must meet the standard regulations of 'material for hydrogen sulfide-containing environment in petroleum and natural gas industry-oil and gas exploitation' GB/T20972, 'metallic material requirement for sulfide stress cracking resistance and stress corrosion cracking resistance of natural gas ground facilities' SY/T0599, 'Steel chemical container material selection regulation' HG/T20581-; the pipeline equipment used in the gas field is made of special steel or stainless steel which resists hydrogen sulfide corrosion.

The "conventional design" in the present invention means: the pipeline equipment used in the gas field can be made of common steel.

"gas reservoir block" in the present invention: the blocks are also called gas field blocks.

"Sulfur" in the present invention: also called elemental sulfur, abbreviated as sulfur.

"packed static mixer" in the present invention: refers to a static mixer with filler inside and the mixing effect is enhanced by the filler.

"labyrinth static mixer" in the present invention: it is a static mixer with a reentrant, honeycomb-like labyrinth structure inside and enhanced mixing effect by the labyrinth structure.

"blowing agent" in the present invention: also known as foaming agent, refers to a viscous substance or/and surfactant that can foam water or aqueous solution.

The technical problem to be solved by the invention is to provide a local natural gas desulfurization method; the method overcomes the defects of the existing natural gas desulfurization method, can enable the sulfur-containing gas well to produce by using the existing gas collecting stations and inter-station pipelines which are built and designed conventionally, can shorten the development and construction period of the gas field, can greatly reduce the fixed investment of the gas field, can greatly improve the development benefit of the gas field, is suitable for the natural gas production of the sulfur-containing gas well, and is particularly suitable for the gas field or block where the sulfur-containing gas well and the sulfur-free gas well coexist; the method has the advantages of easy implementation, safety, reliability, wide application, easy popularization and the like.

In order to solve the above technical problems, a first technical solution adopted by the present invention is:

the invention relates to a local natural gas desulfurization method, which comprises the following steps:

1) firstly, separating a gas-liquid mixture produced by a gas well into natural gas and produced liquid, and then enabling the produced liquid to enter a sewage treatment plant for further treatment;

2) adding oxidant liquid with the content of more than 0.001% into the separated natural gas to oxidize hydrogen sulfide and/or odorous substances in the natural gas to form a sulfur-containing solid-liquid mixture;

3) then the solid-liquid mixture is separated from the natural gas for further treatment, and the natural gas after the solid-liquid mixture is separated is led into an inlet pipeline or/and an inter-station pipeline of a purification device so as to be led into the purification device or/and a natural gas purification treatment plant for further treatment.

Known from the knowledge in the art: the produced liquid of the gas well which does not contain hydrogen sulfide is generally acidic and corrosive, and the anticorrosion technology of the produced liquid pipeline belongs to a mature technology; similarly, the produced liquid of the gas well containing the hydrogen sulfide is generally acidic and corrosive, and the pipeline corrosion prevention technology of the produced liquid containing the hydrogen sulfide belongs to a mature technology; the liquid expansibility in the pipeline is extremely low, and after the produced liquid pipeline in a pressure state is broken, the produced liquid can not be obviously and rapidly expanded to cause explosion accidents, so that the produced liquid containing hydrogen sulfide conveyed by the pipeline meets the production requirement of a gas field.

Known from the knowledge in the art: natural gas purification devices for natural gas dehydration or/and dew point reduction are arranged in some gas gathering stations, generally referred to as dehydration devices or purification devices for short, natural gas with the hydrogen sulfide concentration reaching the standard can be dehydrated by the purification devices, and after the dew point reduction, dry gas is formed and directly enters a dry gas pipeline or an external pipeline without further treatment in a natural gas purification treatment plant; at present, no open documents or successful cases of natural gas desulfurization devices are arranged in domestic gas gathering stations.

Further, in step 1), the gas well may refer to 1 gas well, or may refer to 2 or more than 2 gas wells.

Further, in step 1), the gas-liquid mixture may refer to a gas-liquid mixture produced from 1 gas well, or may refer to a mixture or/and a pool of gas-liquid mixtures produced from 2 or more gas wells.

Known from the knowledge in the art: some gas collecting stations govern 1 gas well.

Further, in order to remove hydrogen sulfide and/or odorous substances in the natural gas more fully, in the step 2), oxidant liquid with the content of more than 0.001% is added to the upper part of the packed tower, the oxidant liquid flows in the packing from top to bottom, and meanwhile, the natural gas enters the lower part of the packed tower and flows in the packing from bottom to top, so that the hydrogen sulfide and/or odorous substances in the natural gas are fully contacted with the oxidant liquid and mixed to be oxidized to form a sulfur-containing solid-liquid mixture; in step 3), the solid-liquid mixture enters the lower part or the bottom of the packed tower and then leaves the packed tower from the lower part or the bottom of the packed tower for further treatment.

Further, in order to remove hydrogen sulfide and/or odorous substances in the natural gas more fully and reduce the scaling and blocking speed of the filler, in the step 2), oxidant liquid with the content of more than 0.001% is added to the upper part of the plate tower, the oxidant liquid flows from top to bottom, and meanwhile, the natural gas enters the lower part of the plate tower and flows from bottom to top, so that the hydrogen sulfide and/or odorous substances in the natural gas are fully contacted with the oxidant liquid, mixed and oxidized to form a sulfur-containing solid-liquid mixture; in step 3), the solid-liquid mixture enters the lower part or the bottom of the plate tower and then leaves the plate tower from the lower part or the bottom of the plate tower for further treatment.

Further, in order to remove the hydrogen sulfide and/or odorous substances in the natural gas more fully and solve the problem of blockage of the filler and the tower plate, in the step 2), oxidant liquid with the content of more than 0.001 percent is added to the upper part of the spray tower, the oxidant liquid flows or drips from top to bottom, and meanwhile, the natural gas enters the lower part of the spray tower and flows from bottom to top, so that the hydrogen sulfide and/or odorous substances in the natural gas are fully contacted with the oxidant liquid, mixed and oxidized to form a sulfur-containing solid-liquid mixture; in the step 3), the solid-liquid mixture enters the lower part or the bottom of the spray tower and then leaves the spray tower from the lower part or the bottom of the spray tower for further treatment.

Further, in order to fully contact and mix the natural gas and the oxidant and reduce the manufacturing cost, in the step 2), oxidant liquid with the content of more than 0.001 percent is added into a closed container, the liquid level height of the oxidant liquid is more than 5cm and lower than the top of the closed container, then the natural gas enters the lower part of the oxidant liquid and flows from bottom to top in the form of bubbles, so that hydrogen sulfide and/or odorous substances in the natural gas are fully contacted and mixed with the oxidant liquid to be oxidized, and a sulfur-containing solid-liquid mixture is formed; in step 3), the solid-liquid mixture leaves the closed container from the bottom or the lower part of the closed container for further treatment.

Further, in order to fully contact and mix the natural gas and the oxidant and reduce the manufacturing cost, in the step 2), oxidant liquid with the content of more than 0.001 percent is added into the natural gas, and then the natural gas enters a static mixer along with the natural gas and is continuously contacted and mixed with the natural gas, so that hydrogen sulfide and/or odorous substances in the natural gas are fully contacted and mixed with the oxidant liquid and are oxidized to form a sulfur-containing solid-liquid mixture; furthermore, the static mixer refers to any one of a packing type static mixer, a labyrinth type static mixer, a vertical static mixer and a horizontal static mixer or any combination of any two or more of the above; in the step 3), the solid-liquid mixture enters a gas-liquid separator or a tower type closed container along with the natural gas, and then the solid-liquid mixture is separated from the natural gas by the gas-liquid separator or the tower type closed container for further treatment.

Further, in order to further enhance the contact and mixing of the natural gas and the oxidant liquid in the static mixer, in the step 2), the oxidant liquid with the content of more than 0.001 percent and the natural gas enter the bottom of the static mixer filled with the filler, and are continuously contacted and mixed by the filler; and 3) allowing the solid-liquid mixture and the natural gas to enter a gas-liquid separator or a tower type closed container from the top of the static mixer.

Further, in order to further enhance the contact and mixing of the natural gas and the oxidant liquid, in step 2, the oxidant liquid with the content of more than 0.001% enters the atomizer to be atomized into tiny droplets and contacts and mixes with the natural gas, so that hydrogen sulfide and/or odorous substances in the natural gas fully contact and mix with the oxidant liquid to be oxidized, and a sulfur-containing solid-liquid mixture is formed; furthermore, the atomizer is a device capable of making liquid into micro-droplets (or liquid droplets), and may be any one of a mechanical atomizer, an ultrasonic atomizer, and an electric atomizer, or any combination of any two or more thereof; in the step 3), the solid-liquid mixture enters a gas-liquid separator or a tower type closed container along with the natural gas, and then the solid-liquid mixture is separated from the natural gas by the gas-liquid separator or the tower type closed container for further treatment.

Further, in order to recycle the oxidant or recover the sulfur, in the step 3), the solid-liquid mixture is sent to a regeneration system to be regenerated into oxidant suspension with the oxidant content being more than 0.001 percent; then sending the oxidant suspension into a solid-liquid separation system to be separated into sulfur paste (or sulfur solid) and oxidant liquid with the content of more than 0.001 percent, further recycling or harmlessly treating the sulfur paste (or sulfur solid), and sending the oxidant liquid with the content of more than 0.001 percent into a medicament tank; then adding the oxidant liquid with the content of more than 0.001% into the natural gas so as to recycle the oxidant liquid.

Further, in order to better recycle the oxidant and recover the sulfur, in the step 3), the solid-liquid mixture is sent to a regeneration system comprising a shell, a medicine outlet pipeline, a sulfur foam outlet flow channel, an air outlet pipe and an air inlet pipe, so that the liquid in the solid-liquid mixture is regenerated into oxidant liquid with the oxidant content of more than 0.001%, the solid and the sulfur in the solid-liquid mixture are floated to the liquid level by air bubbles to form sulfur foam and the oxidant liquid with the oxidant content of more than 0.001%, and the oxidant liquid with the oxidant content of more than 0.001% is sent to a medicament tank; then the sulfur foam enters a solid-liquid separation system and is separated into sulfur paste (or sulfur solid) and oxidant liquid with the content of more than 0.001 percent, the sulfur paste (or sulfur solid) is further recycled or treated in a harmless way, and the oxidant liquid with the content of more than 0.001 percent is sent into a medicament tank; then adding the oxidant liquid with the content of more than 0.001 percent in the medicament tank into the natural gas so as to recycle the oxidant liquid. Furthermore, in order to enhance the effect of the air bubble flotation of the sulfur solids, in the step 3), a foaming agent and a flocculating agent are added into the solid-liquid mixture or the regeneration system. Furthermore, in order to enhance the effect of the sulfur solid matter floatation by the bubbles, in the step 3), the air inlet pipe is positioned at the bottom of the solid-liquid mixture and is provided with an air distribution device.

Further, in order to recycle the oxidant or recover the sulfur, in the step 3), the solid-liquid mixture is sent to a solid-liquid separation system to be separated into sulfur paste (or sulfur solid) and liquid, the sulfur paste (or sulfur solid) is further recycled or subjected to innocent treatment, and the liquid is sent to a regeneration system to be regenerated into oxidant liquid with the oxidant content being more than 0.001%; then adding the oxidant liquid with the content of more than 0.001% into the natural gas so as to recycle the oxidant liquid.

Further, in order to intensively regenerate the oxidant or intensively recover the sulfur, in the step 3), the solid-liquid mixture is firstly transported to a regeneration place, and then the solid-liquid mixture is sent to a regeneration system to be regenerated into an oxidant suspension with the oxidant content being more than 0.001 percent; then sending the oxidant suspension into a solid-liquid separation system to be separated into sulfur paste (or sulfur solid) and oxidant liquid with the content of more than 0.001%, and further recycling or harmlessly treating the separated sulfur paste (or sulfur solid); then adding the separated oxidant liquid with the content of more than 0.001% into the natural gas so as to recycle the oxidant liquid.

Further, in order to intensively regenerate the oxidant or intensively recover the sulfur, in the step 3), the solid-liquid mixture is firstly transported to a regeneration place by a vehicle, then the solid-liquid mixture is sent to a solid-liquid separation system to be separated into sulfur paste (or sulfur solid) and liquid, and the separated sulfur paste (or sulfur solid) is further recycled or subjected to harmless treatment; then the separated liquid is sent into a regeneration system to be regenerated into oxidant liquid with the oxidant content being more than 0.001 percent; then the regenerated oxidant liquid with the content of more than 0.001 percent is added into the natural gas so as to recycle the oxidant liquid.

Further, in order to reduce the corrosion rate of the produced liquid pipeline, in step 1), firstly, an oxidant or an oxidant liquid with the content of more than 0.001% or/and alkali is added into the produced liquid, so that hydrogen sulfide and/or odorous substances in the produced liquid are oxidized or/and a chemical reaction is generated, and a produced liquid mixture containing sulfur or/and solids is formed; then separating out sulfur and solid in the produced liquid mixture for further treatment; then the produced liquid with separated sulfur and solid enters a sewage treatment plant for further treatment.

Further, in order to reduce the consumption of the reducing solid matters on the oxidant and reduce the dosing cost, in the step 1), the solid matters in the produced liquid are separated and further processed; then adding an oxidant or oxidant liquid with the content of more than 0.001% or/and alkali into the produced liquid after solid separation, so that hydrogen sulfide and/or odorous substances in the produced liquid are oxidized or/and generate chemical reaction to form a produced liquid mixture containing sulfur or/and solid; then separating out sulfur and solid in the produced liquid mixture for further treatment; then the produced liquid with separated sulfur and solid enters a sewage treatment plant for further treatment.

Further, in order to fully oxidize the hydrogen sulfide and/or the odorous substances and reduce the dosing cost, in the step 1), firstly, an oxidant or an oxidant aqueous solution with the content of more than 0.001% or/and alkali is added into the produced liquid and enters a closed reaction container or a static mixer, so that the hydrogen sulfide and/or the odorous substances in the produced liquid are fully oxidized or/and generate a chemical reaction to form a produced liquid mixture containing sulfur or/and solids; then separating out sulfur and solid in the produced liquid mixture for further treatment; then the produced liquid with separated sulfur and solid enters a sewage treatment plant for further treatment. Preferably, the static mixer is any one of a packing static mixer, a labyrinth static mixer, a vertical static mixer and a horizontal static mixer or any combination of any two or more of the above.

Further, in order to fully oxidize hydrogen sulfide and/or odorous substances and reduce the dosing cost, in the step 1), solid matters in the produced liquid are separated and further processed; then adding an oxidant or an oxidant aqueous solution with the content of more than 0.001% or/and alkali into the produced liquid and enabling the produced liquid to enter a closed reaction vessel or a static mixer so as to oxidize hydrogen sulfide and/or odorous substances in the produced liquid or/and generate a chemical reaction to form a produced liquid mixture containing sulfur or/and solids; then separating out sulfur and solid in the produced liquid mixture for further treatment; then the produced liquid with separated sulfur and solid enters a sewage treatment plant for further treatment. Preferably, the static mixer is any one of a packing static mixer, a labyrinth static mixer, a vertical static mixer and a horizontal static mixer or any combination of any two or more of the above.

Further, the oxidant is any one of chlorate, perchlorate, permanganate, peroxide, hydrogen peroxide, fluorine, chlorine, bromine, iodine, ferric salt, cupric salt, trivalent cupric salt, tetravalent cupric salt, complex iron and chelated iron or a mixture of more than two of the above components which do not generate chemical reaction after being mixed in any proportion.

Further, the oxidant liquid is a mixed solution of methanol and water as an oxidant in an arbitrary ratio.

Further, the oxidizer liquid is a methanol solution of an oxidizer.

Further, the oxidant liquid is an aqueous solution or/and an alcoholic solution of a ferric iron complex having a PH greater than 7.5.

Furthermore, in order to prevent the winter icing, the oxidant liquid contains 5-60% of organic acid salt.

In order to solve the above technical problem, the second technical solution adopted by the present invention is:

a local area type natural gas desulfurization method comprises the following steps:

1) firstly, separating a gas-liquid mixture produced by a gas well into natural gas and produced liquid, and then transporting the produced liquid by a tank truck for further treatment;

3) then the solid-liquid mixture is separated from the natural gas, and the natural gas after the solid-liquid mixture is separated is led into an inlet pipeline or/and an inter-station pipeline of a purification device so as to be further processed in the purification device or/and a natural gas purification treatment plant.

Further, in order to prevent the produced liquid from volatilizing (or separating out) hydrogen sulfide to pollute the atmosphere, in the step 1), firstly, oxidizing agent or aqueous solution of the oxidizing agent with the content of more than 0.001% or/and alkali produced liquid to oxidize the hydrogen sulfide and/or odor substances in the produced liquid or/and generate chemical reaction to form a produced liquid mixture containing sulfur or/and solid; and then the produced liquid mixture is sent to a sewage treatment plant for further treatment by a tank truck.

Further, in order to better prevent the produced liquid from volatilizing (or separating out) hydrogen sulfide to pollute the atmosphere, in the step 1), firstly, an oxidant or an oxidant aqueous solution with the content of more than 0.001% or/and alkali is added into the produced liquid and enters a closed reaction container or a static mixer, so that the hydrogen sulfide and/or odorous substances in the produced liquid are fully oxidized or/and generate chemical reaction, and a produced liquid mixture containing sulfur or/and solid is formed; and then the produced liquid mixture is sent to a sewage treatment plant for further treatment by a tank truck.

Further, in order to prevent the mixture from blocking pipeline equipment and pipeline valves of the automobile tank car, in the step 1), firstly, an oxidant or an oxidant aqueous solution with the content of more than 0.001% or/and alkali is added into the produced liquid, so that hydrogen sulfide and/or odorous substances in the produced liquid are oxidized or/and generate chemical reaction, and a produced liquid mixture containing sulfur or/and solid is formed; then, separating sulfur and solid matters in the produced liquid mixture by using solid-liquid separation equipment for further treatment; then the produced liquid after separating out sulfur and solid is sent to a sewage treatment plant for further treatment by a tank car.

Further, the oxidant liquid is a mixed solution of methanol and water as oxidants in any proportion.

Further, the oxidant liquid is a methanol solution of an oxidant.

Furthermore, in order to prevent the winter icing, the oxidant aqueous solution contains 5-60% of organic acid salt.

In order to solve the above technical problems, the third technical solution adopted by the present invention is:

1) firstly, separating a gas-liquid mixture produced by a gas well into natural gas and produced liquid; then evaporating the water in the produced liquid by an evaporation method; then carrying out further treatment on the residual concentrated solution or residue of the extracted liquid after water evaporation;

Further, in order to prevent the produced liquid from volatilizing (or separating out) hydrogen sulfide to pollute the atmosphere, in the step 1), firstly, an oxidant or an oxidant aqueous solution with the content of more than 0.001% or/and alkali is added into the produced liquid, so that the hydrogen sulfide and/or odorous substances in the produced liquid are fully oxidized or/and chemically reacted, and a produced liquid mixture containing sulfur or/and solid is formed; then evaporating the water in the produced liquid mixture by an evaporation method; the concentrate or residue of the produced fluid mixture remaining after evaporation of water is then transported away for further processing.

Further, in order to prevent the produced liquid from volatilizing (or separating out) hydrogen sulfide to pollute the atmosphere, in the step 1), firstly, an oxidant or an oxidant aqueous solution with the content of more than 0.001% or/and alkali is added into the produced liquid and enters a closed reaction container or a static mixer, so that the hydrogen sulfide and/or odorous substances in the produced liquid are fully oxidized or/and generate a chemical reaction, and a produced liquid mixture containing sulfur or/and solid is formed; then evaporating the water in the produced liquid mixture by an evaporation method; the concentrate or residue of the produced fluid mixture remaining after evaporation of water is then transported away for further processing.

Further, the evaporation method refers to any one of heating evaporation and ventilation evaporation or any combination thereof.

The invention has the following beneficial effects: the method overcomes the defects of the existing natural gas desulfurization method, can enable the sulfur-containing gas well to produce by using the existing gas collecting stations and inter-station pipelines which are built and designed conventionally, can greatly reduce the fixed investment of the gas field, can greatly improve the development benefit of the gas field, and is particularly suitable for the gas field or block where the sulfur-containing gas well and the sulfur-free gas well coexist; the method has the advantages of easy implementation, safety, reliability, wide application, easy popularization and the like.

Drawings

The following detailed description of embodiments of the invention is provided in connection with the accompanying drawings

FIG. 1 is a schematic diagram of a ground production system of a conventional gas gathering station produced liquid pipe transportation-centralized desulfurization method;

FIG. 2 is a schematic diagram of a ground production system of a conventional gas gathering station mining tank truck hauling-centralized desulfurization method;

FIG. 3 is a schematic diagram of a process for the desulfurization of natural gas in a localized manner in example 1;

FIG. 4 is a schematic view of a laboratory test apparatus in example 1;

FIG. 5 is a schematic diagram of a localized natural gas desulfurization process in example 2;

FIG. 6 is a schematic diagram of a localized natural gas desulfurization process in example 3;

FIG. 7 is a schematic diagram of a localized natural gas desulfurization process in example 4;

FIG. 8 is a schematic diagram of a localized natural gas desulfurization process in example 5;

FIG. 9 is a schematic diagram of a localized natural gas desulfurization process in example 6;

FIG. 10 is a schematic view of a localized natural gas desulfurization process in example 7;

FIG. 11 is a schematic view of a localized natural gas desulfurization process in example 8;

FIG. 12 is a schematic view of a localized natural gas desulfurization process in example 9;

FIG. 13 is a schematic view of a localized natural gas desulfurization process in example 10;

FIG. 14 is a schematic view of a localized natural gas desulfurization process in example 11;

FIG. 15 is a schematic view of a localized natural gas desulfurization process in example 12;

FIG. 16 is a schematic view of a localized natural gas desulfurization process in example 13;

FIG. 17 is a schematic view of a localized natural gas desulfurization process in example 14;

FIG. 18 is a schematic view of a localized natural gas desulfurization method in example 17;

FIG. 19 is a schematic view of a localized natural gas desulfurization process in example 18;

FIG. 20 is a schematic view of a localized natural gas desulfurization process in example 19;

FIG. 21 is a schematic view of a localized natural gas desulfurization method in example 20;

FIG. 22 is a schematic view of a localized natural gas desulfurization method in example 21;

FIG. 23 is a schematic view of a localized natural gas desulfurization method in example 22;

FIG. 24 is a schematic view of a localized natural gas desulfurization method in example 23;

FIG. 25 is a schematic view of a localized natural gas desulfurization method in example 24;

FIG. 26 is a schematic view of a localized natural gas desulfurization method in example 25;

FIG. 27 is a schematic view of a localized natural gas desulfurization method in example 26;

FIG. 28 is a schematic view of a localized natural gas desulfurization method in example 27;

FIG. 29 is a schematic view of a localized natural gas desulfurization method in example 28;

FIG. 30 is a schematic view of a localized natural gas desulfurization method in example 29;

FIG. 31 is a schematic view of a localized natural gas desulfurization method in example 30.

Detailed Description

Example 1

Referring to fig. 3, a local area type natural gas desulfurization method includes the following steps:

1) gas-liquid mixture produced by the gas well 100 enters the header 301 through the valve 101 and the gas collecting pipeline 102, and gas-liquid mixture produced by the gas well 308 enters the header 301 through the valve 309 and the gas collecting pipeline 310, so that the gas-liquid mixture produced by different gas wells can be collected into the header 301; then the gas-liquid mixture of the collecting pipe 301 enters a gas-liquid separator 300 to be separated into natural gas and produced liquid, and then the produced liquid enters a produced liquid pipeline 107 through a liquid outlet pipeline 302 so as to enter a sewage treatment plant 108 for further treatment;

2) adding an oxidant aqueous solution with the content of more than 0.001% into the natural gas separated from the gas-liquid separator 300 and entering the pipeline 303 by using a medicine adding pipeline 304, so that hydrogen sulfide and/or odorous substances in the natural gas are oxidized to form a sulfur-containing solid-liquid mixture;

3) then the gas-liquid separator (or tower type closed container) 305 separates the solid-liquid mixture from the natural gas and enters a solid-liquid outlet pipeline 307 for further processing, and the natural gas after the solid-liquid mixture is separated enters the inter-station pipeline 104 through a natural gas outlet pipeline 306 so as to enter the natural gas purification processing plant 105 for further processing.

Known from the knowledge in the art: a gas-liquid separator is called separator for short, and the gas-liquid separator and a tower type closed container are used for separating gas-liquid mixture, which belongs to a mature method; the method is a mature method for separating gas from suspension and slurry by using a gas-liquid separator and a tower-type closed container; the tower-type closed container generally refers to a cylindrical closed container having a height larger than an inner diameter, and sometimes refers to a rectangular closed container having a height larger than a width.

The indoor experiment shows that: with ferric ions F_e ⁺³An aqueous complex solution is exemplified. Referring to FIG. 4, the lower portion of the glass container 400 contains 2% of the ferric ions F_e ⁺³An aqueous complex solution 401 with a void formed in the upper partA chamber 405, the top of which is sealed with a sealing member 404, and a natural gas inlet pipe 402 inserted into the lower part of the glass container 400 through the sealing member 404 to supply ferric ions F_e ⁺³The complex solution 401 is filled to the bottom of the glass container 400, and a natural gas outlet pipe 403 is inserted into a cavity 405 in the upper part of the glass container 400 through a sealing piece 404; the hydrogen sulfide content was allowed to reach 200mg/m³The natural gas is fed into the ferric ion F with the liquid level height of 500 mm through the natural gas inlet pipe 402 at the flow rate of 0.1 liter/second_e ⁺³In the aqueous complex solution 401, and then rises to the ferric ion F_e ⁺³The water solution 401 of the complex enters the cavity 405 at the upper part of the glass container 400 at the liquid level, and then the hydrogen sulfide content of the water solution of the complex is reduced to 120mg/m after the water solution of the complex leaves the glass container 400 through the natural gas outlet pipe 403³Therefore, the desulfurization rate of the natural gas is calculated to be 40 percent; further experiments showed that: continuously reducing the hydrogen sulfide content to 200mg/m³The flow rate of the natural gas passing through the natural gas inlet pipe 402 (or the content of hydrogen sulfide from the natural gas outlet pipe 403 is 120 mg/m)³The natural gas enters the natural gas inlet pipe 402) for multiple cycles, and the content of the hydrogen sulfide after the natural gas leaves the glass container 400 can be reduced to 15mg/m³Meets the regulation of natural gas GB 17820-2018; further experiments showed that: with the hydrogen sulfide content of 200mg/m³The natural gas continuously enters into ferric ion F_e ⁺³In the complex aqueous solution 401, yellowish or offwhite particles are formed by visual inspection, and further experimental detection shows that the main component of the yellowish or offwhite particles is sulfur; further tests show that: stopping natural gas from entering ferric ion F_e ⁺³In the complex aqueous solution 401, the trivalent ferric ions F will form light yellow or off-white particles_e ⁺³The aqueous complex 401 is allowed to stand for 2 hours without the light yellow or off-white particles precipitating to the bottom of the glass container 400, i.e., ferric ions F_e ⁺³The complex aqueous solution 401 and the generated sulfur can form a suspension or a solid-liquid mixture with good fluidity; further tests show that: ferric ion F to generate light yellow or grey white particles_e ⁺³The aqueous complex solution 401 was left to stand for 7 daysThereafter, yellowish or grayish white particles are precipitated on the ferric ion F_e ⁺³Bottom of the complex aqueous solution 401.

Thus, it can be seen that: the solid-liquid mixture formed by adding the aqueous oxidant solution to the natural gas in the pipeline 303 can smoothly enter the gas-liquid separator 305; the solid-liquid mixture can be separated from the natural gas in the gas-liquid separator 305 and enter the solid-liquid outlet line 307.

Example 2

Referring to fig. 5, example 1 is repeated except that: in order to simplify the process flow and facilitate management, in step 1), the gas-liquid mixture produced by the gas well 100 enters the gas-liquid separator 300 through the valve 101 and the gas collecting pipeline 102 to be separated into natural gas and produced liquid, and then the produced liquid enters the produced liquid pipeline 107 through the liquid outlet pipeline 302 to enter the sewage treatment plant 108 for further treatment.

Example 3

Referring to fig. 6, example 1 is repeated except that: in order to simplify the process flow and facilitate management, in step 3), the gas-liquid separator (or tower-type closed container) 305 separates the solid-liquid mixture from the natural gas, and the mixture enters the solid-liquid outlet pipeline 307 for further treatment, and then the natural gas after separation of the solid-liquid mixture enters the inlet pipeline 601 of the purification device 600 through the natural gas outlet pipeline 306, so as to enter the purification device 600 for further treatment and then enter the purified natural gas (or dry gas) pipeline 602.

Known from the knowledge in the art: purified natural gas is also called dry gas, commodity gas and external transportation gas, and generally refers to natural gas meeting external transportation requirements or the standard of natural gas GB 17820-2018.

Example 4

Referring to fig. 7, example 2 was repeated except that: in order to simplify the process flow and facilitate management, in step 3), the gas-liquid separator (or tower-type closed container) 305 separates the solid-liquid mixture from the natural gas, and the mixture enters the solid-liquid outlet pipeline 307 for further treatment, and then the natural gas after separation of the solid-liquid mixture enters the inlet pipeline 601 of the purification device 600 through the natural gas outlet pipeline 306, so as to enter the purification device 600 for further treatment and then enter the purified natural gas (or dry gas) pipeline 602.

Example 5

Referring to fig. 8, examples 1-4 are repeated except that: in order to remove hydrogen sulfide and/or odorous substances in the natural gas more fully, in the step 2), an oxidant aqueous solution with the content of more than 0.001% is added to the upper part of a filler 801 in a filler tower 800 by a medicine adding pipeline 304, the oxidant aqueous solution flows in the filler 801 from top to bottom, and simultaneously, the natural gas separated from a gas-liquid separator 300 enters the lower part of the filler 801 in the filler tower 800 through a pipeline 303 and flows in the filler 801 from bottom to top, so that the hydrogen sulfide and/or odorous substances in the natural gas are fully contacted with the oxidant aqueous solution, mixed and oxidized to form a sulfur-containing solid-liquid mixture;

in step 3), the solid-liquid mixture enters the lower part or the bottom of the packed tower 800 and then leaves the packed tower 800 from a solid-liquid outlet pipeline 307 at the lower part or the bottom of the packed tower 800 for further treatment; and natural gas is allowed to enter the natural gas outlet line 306 from the top or upper portion of the packed tower 800.

Known from the knowledge in the art: the packing tower and the packing belong to mature technologies, and Raschig rings, pall rings, porcelain rings, clay sinter, metal powder sinter, metal fibers, plastic fibers, chemical fibers, plant fibers, nets, fiber substances and porous substances can be used as the packing.

Example 6

Referring to fig. 9, examples 1-4 were repeated except that: in order to remove hydrogen sulfide and/or odorous substances in the natural gas more fully and reduce the scaling and blocking speed of the filler, in the step 2), an oxidant aqueous solution with the content of more than 0.001% is added to the upper part of the plate tower 900 by a medicine adding pipeline 304, the oxidant aqueous solution flows from top to bottom, and simultaneously, the natural gas separated from the gas-liquid separator 300 enters the lower part of the plate tower 900 through a pipeline 303 and flows from bottom to top, so that the hydrogen sulfide and/or odorous substances in the natural gas are fully contacted with the oxidant aqueous solution, mixed and oxidized to form a sulfur-containing solid-liquid mixture;

in step 3), the solid-liquid mixture enters the lower part or the bottom of the plate tower 900, and then leaves the plate tower 900 from a solid-liquid outlet pipeline 307 at the lower part or the bottom of the plate tower 900 for further treatment; and natural gas is allowed to enter natural gas outlet line 306 from the top or upper portion of tray tower 900.

Example 7

Referring to fig. 10, examples 1-4 are repeated except that: in order to remove hydrogen sulfide and/or odorous substances in natural gas more fully and solve the problem of blockage of fillers and tower plates, in the step 2), an oxidant aqueous solution with the content of more than 0.001% is added to the upper part of a spray tower 1000 through a spray device 1001 by a medicine adding pipeline 304, the oxidant aqueous solution flows or drops from top to bottom, and meanwhile, natural gas separated from a gas-liquid separator 300 enters the lower part of the spray tower 1000 through a pipeline 303 and flows from bottom to top, so that the hydrogen sulfide and/or odorous substances in the natural gas are fully contacted with the oxidant aqueous solution, mixed and oxidized to form a sulfur-containing solid-liquid mixture; the spraying device 1001 is a device capable of dripping or spraying liquid, and can be any one of a spray header, a spray pipe, a spray atomizer, a mechanical atomizer and an ultrasonic atomizer or any combination of more than two of the spray header, the spray pipe, the spray atomizer and the ultrasonic atomizer;

in step 3), the solid-liquid mixture enters the lower part or the bottom of the spray tower 1000, and then leaves the spray tower 1000 from a solid-liquid outlet pipeline 307 at the lower part or the bottom of the spray tower 1000 for further treatment; and allows natural gas to enter the natural gas outlet line 306 from the top or upper portion of the spray tower 1000.

Example 8

Referring to fig. 11, examples 1-4 are repeated except that: in order to fully contact and mix the natural gas and the oxidant and reduce the manufacturing cost, in the step 2), an oxidant aqueous solution 1102 with the content of more than 0.001 percent is added into a closed container 1100 by a medicine adding pipeline 304, the liquid level height of the oxidant aqueous solution 1102 is more than 5cm and less than 5cm of the top of the closed container 1100, the natural gas separated from a gas-liquid separator 300 sequentially passes through a pipeline 303 and is inserted into a pipeline 1101 to enter the lower part of the oxidant aqueous solution 1102, and the natural gas flows from bottom to top in the form of bubbles 1103, so that hydrogen sulfide and/or odor substances in the natural gas are fully contacted and mixed with the oxidant aqueous solution and are oxidized to form a sulfur-containing solid-liquid mixture;

in step 3), the solid-liquid mixture leaves the closed container 1100 for further treatment from a solid-liquid outlet line 307 at the bottom or lower part of the closed container 1100; and allows natural gas to enter natural gas outlet line 306 from the top or upper portion of containment vessel 1100.

The indoor experiment shows that: referring to FIG. 4, the ferric ion F_e ⁺³Standing a solid-liquid mixture formed by the complex aqueous solution and the natural gas for 2 hours without layering and precipitation; the solid-liquid mixture can thus exit the closed vessel 1100 through the solid-liquid outlet line 307 at the bottom or lower portion of the closed vessel 1100.

Example 9

Referring to fig. 12, examples 1-4 were repeated except that: in order to fully contact and mix the natural gas and the oxidant and reduce the manufacturing cost, in the step 2), the oxidant aqueous solution with the content of more than 0.001 percent is added into the natural gas which is separated from the gas-liquid separator 300 and enters the pipeline 303 by the medicine adding pipeline 304, and then the natural gas enters the static mixer 1200 along with the natural gas and is continuously contacted and mixed with the natural gas, so that the hydrogen sulfide and/or the odor substances in the natural gas are fully contacted and mixed with the oxidant aqueous solution and are oxidized to form a sulfur-containing solid-liquid mixture; the static mixer 1200 is any one of a packing type static mixer, a labyrinth type static mixer, a vertical static mixer and a horizontal static mixer or any combination of any two or more of the above;

in step 3), the solid-liquid mixture enters a gas-liquid separator (or tower type closed container) 305 along with the natural gas through a connecting pipeline 1201, then the solid-liquid mixture is separated from the natural gas by the gas-liquid separator (or tower type closed container) 305 and enters a solid-liquid outlet pipeline 307 for further treatment, and then the natural gas after the solid-liquid mixture is separated enters a natural gas outlet pipeline 306.

Known from the knowledge in the art: the gas-liquid mixing with a static mixer belongs to the mature technology.

Example 10

Referring to fig. 13, examples 1-4, 9 were repeated except that: in order to further enhance the contact and mixing of the natural gas and the oxidant aqueous solution in the static mixer, in the step 2), the oxidant aqueous solution with the content of more than 0.001 percent and the natural gas enter the bottom of the static mixer 1300 filled with the filler 1301, and are continuously contacted and mixed by the filler 1301;

in step 3), the solid-liquid mixture and the natural gas are introduced into the gas-liquid separator (or the tower-type closed vessel) 305 from the top of the static mixer 1300 through the connecting line 1201.

Example 11

Referring to fig. 14, examples 1-4 were repeated except that: in order to further enhance the contact and mixing of the natural gas and the oxidant aqueous solution, in step 2, the oxidant aqueous solution with the content of more than 0.001% enters the atomizer 1400 by using the medicine feeding pipeline 304 to be atomized into tiny droplets and is contacted and mixed with the natural gas which is separated from the gas-liquid separator 300 and enters the pipeline 303, so that the hydrogen sulfide and/or the odorous substances in the natural gas are fully contacted and mixed with the oxidant aqueous solution to be oxidized, and a sulfur-containing solid-liquid mixture is formed; the atomizer 1400 is a device capable of making liquid into micro-droplets (or liquid droplets), and may be any one of a mechanical atomizer, an ultrasonic atomizer, and an electric atomizer, or any combination of any two or more thereof;

Known from the knowledge in the art: the air flow premixing atomizer, the air flow injection atomizer, the high pressure jet (jet) atomizer, the nozzle atomizer, the air flow atomizer and the rotary cup type atomizer are all mechanical atomizers.

Example 12

Referring to fig. 15, examples 1-11 were repeated except that: in order to recycle the oxidant or recover the sulfur, in the step 3), the solid-liquid mixture is sent to the regeneration system 1500 through the solid-liquid outlet pipeline 307 to be regenerated into a suspension liquid with the oxidant content more than 0.001%; then sending the oxidant suspension into a solid-liquid separation system 1502 through a suspension pipeline 1501 to be separated into sulfur paste (or sulfur solid) and oxidant aqueous solution with the content of more than 0.001%, further recycling or harmlessly treating the sulfur paste (or sulfur solid), and sending the oxidant aqueous solution with the content of more than 0.001% into a medicament tank 1504 through a tank inlet pipeline 1503; then, the oxidant aqueous solution with the content of more than 0.001 percent is added into the natural gas which is separated from the gas-liquid separator 300 and enters the pipeline 303 through the pump inlet pipeline 1505, the pump 1506 and the medicine adding pipeline 304, so that the oxidant aqueous solution can be recycled.

Known from the knowledge in the art: the medicament tank can be a round container, and can also be a square or other-shaped container; the preparation of sulfur from sulfur paste (or sulfur solid) belongs to the mature technology.

Indoor tests show that: as shown in FIG. 4, with ferric ion F_e ⁺³An aqueous solution of the complex with a content of 2% is taken as an example; when the content of hydrogen sulfide is 200mg/m³At a flow rate of 0.5 l/s into the ferric ions F_e ⁺³After 3 hours in the complex aqueous solution 401 with the content of 2%, a large amount of particles suspended in the complex aqueous solution 401 can be visually detected, and the detection shows that the content of the hydrogen sulfide in the natural gas of the natural gas outlet pipe 403 reaches 195mg/m³Above, it is thus demonstrated that the aqueous complex solution 401 is no longer effective in reducing the hydrogen sulfide content of natural gas; further detection shows that the main component of the suspended particles in the complex aqueous solution 401 is sulfur; further detection shows that a large amount of ferrous ions F are formed in the complex aqueous solution 401_e ⁺²It was confirmed that the ferric ion F in the aqueous complex solution 401_e ⁺³Has been reduced to ferrous ions F_e ⁺²。

Further tests show that: air was introduced into the aqueous complex solution 401 in which a large number of fine particles were suspended at a flow rate of 0.5 liter/sec for 3 hoursThe suspended particles in the aqueous complex solution 401 were visually observed to float to the liquid surface and form foam solids; filtering out the fine particles and the liquid surface floating matter in the aqueous complex solution 401 with filter paper to clear the aqueous complex solution 401, and then adjusting the hydrogen sulfide content to 200mg/m³The natural gas is introduced into the clear complex aqueous solution 401 at a flow rate of 0.5 liter/second, then the suspended particles are continuously generated in the complex aqueous solution 401 again by visual inspection, and meanwhile, the content of the hydrogen sulfide in the natural gas outlet pipe 403 is detected to be lower than 130mg/m³From this calculation, the desulfurization rate of the natural gas was found to be 35%.

Further comparative experiments showed that: filtering out suspended particles in the complex aqueous solution 401 by using filter paper to ensure that the complex aqueous solution 401 is clear; then, air was introduced into the clear aqueous complex solution 401 at a flow rate of 0.5 l/sec for 3 hours, and it was visually confirmed that the aqueous complex solution 401 had a clear appearance and no solid fine particles were formed; then, the clear aqueous complex solution 401 was introduced with a hydrogen sulfide content of 200mg/m at a flow rate of 0.5 liter/sec³The suspended particles are continuously generated in the complex aqueous solution 401 again by visual inspection, and the content of the hydrogen sulfide in the natural gas outlet pipe 403 is lower than 150mg/m by detection³From this calculation, the desulfurization rate of the natural gas was found to be 25%.

This proves that: the air can absorb ferric iron ions F which can not effectively reduce the content of the hydrogen sulfide in the natural gas_e ⁺³The complex aqueous solution 401 is regenerated so that it again has the ability to effectively reduce the hydrogen sulfide content of the natural gas.

Example 13

Referring to fig. 16, examples 1-11, 12 are repeated with the following differences: in order to better recycle the oxidant and recover the sulfur, in step 3), the solid-liquid mixture is sent to a regeneration system 1600 comprising a shell 1601, a medicine outlet pipeline 1602, a sulfur foam outlet flow passage 1603, an air outlet pipe 1604 and an air inlet pipe 1605 through a solid-liquid outlet pipeline 307, so that the liquid in the solid-liquid mixture 1606 is regenerated into an oxidant aqueous solution with the oxidant content of more than 0.001%, the solid and the sulfur in the solid-liquid mixture 1606 are floated to the liquid level by air bubbles 1607 to form a sulfur foam and the oxidant aqueous solution with the oxidant content of more than 0.001%, and the oxidant aqueous solution with the oxidant content of more than 0.001% is sent into a medicine tank 1504 through the medicine outlet pipeline 1602; then, the sulfur foam enters a solid-liquid separation system 1502 through a sulfur foam outlet flow passage 1603 and is separated into sulfur paste (or sulfur solid) and an oxidant aqueous solution with the content of more than 0.001%, the sulfur paste (or sulfur solid) is further recycled or subjected to harmless treatment, and the oxidant aqueous solution with the content of more than 0.001% is sent into a medicament tank 1504 through a tank inlet pipeline 1503; then, the oxidant aqueous solution with the content of more than 0.001% in the chemical tank 1504 is added into the natural gas which is separated from the gas-liquid separator 300 and enters the pipeline 303 through the pump inlet pipeline 1505, the pump 1506 and the chemical feeding pipeline 304, so that the oxidant aqueous solution can be recycled.

Further, in order to enhance the effect of the sulfur solid by the air bubble flotation, in the step 3), a foaming agent and a flocculating agent are added into the solid-liquid mixture 1606 or the solid-liquid outlet pipeline 307 and the regeneration system 1600.

Further, in order to enhance the effect of the sulfur solid by the bubble flotation, in step 3), the air inlet pipe 1605 is located at the bottom of the solid-liquid mixture 1606 and is provided with an air distribution device.

Known from the knowledge in the art: introducing air into the suspension to generate a foam flotation (air flotation for short) effect, and floating the solid matter to the liquid surface; the flow channel can be used for flowing liquid and gas, or flowing or sliding pulp, solid-liquid mixture and foam solid, and can be a closed tubular object or a semi-open slideway object; the holes and slots on the pipeline, the fabric tube and the porous substance can be used to make the air uniformly distributed in the liquid, which is a common air distribution device in the field.

Example 14

Referring to fig. 17, examples 1-11, 12 are repeated with the following differences: in order to recycle the oxidant or recover the sulfur, in step 3), the solid-liquid mixture is sent to the solid-liquid separation system 1502 through the solid-liquid outlet pipeline 307 to be separated into sulfur paste (or sulfur solid) and liquid, the sulfur paste (or sulfur solid) is further recycled or subjected to innocent treatment, and the liquid is sent to the regeneration system 1500 through the liquid pipeline 1700 to be regenerated into an oxidant aqueous solution with the oxidant content of more than 0.001%; then, the oxidant aqueous solution with the content of more than 0.001 percent is added into the natural gas which is separated from the gas-liquid separator 300 and enters the pipeline 303 through the medicine inlet pipeline 1701, the pump 1506 and the medicine adding pipeline 304, so that the oxidant aqueous solution can be recycled.

Example 15

Examples 1-11 were repeated with the following differences: in order to intensively regenerate the oxidant or intensively recover the sulfur, in the step 3), the solid-liquid mixture is firstly transported to a regeneration place, and then the solid-liquid mixture is sent to a regeneration system to be regenerated into oxidant suspension with the oxidant content being more than 0.001 percent; then sending the oxidant suspension into a solid-liquid separation system to be separated into sulfur paste (or sulfur solid) and oxidant liquid with the content of more than 0.001%, and further recycling or harmlessly treating the separated sulfur paste (or sulfur solid); then adding the separated oxidant liquid with the content of more than 0.001% into the natural gas so as to recycle the oxidant liquid.

Example 16

Examples 1-11 were repeated with the following differences: in order to intensively regenerate the oxidant or intensively recover the sulfur, in the step 3), the solid-liquid mixture is firstly transported to a regeneration place by a vehicle, then the solid-liquid mixture is sent to a solid-liquid separation system to be separated into sulfur paste (or sulfur solid) and liquid, and the separated sulfur paste (or sulfur solid) is further recycled or subjected to harmless treatment; then the separated liquid is sent into a regeneration system to be regenerated into oxidant liquid with the oxidant content being more than 0.001 percent; then the regenerated oxidant liquid with the content of more than 0.001 percent is added into the natural gas so as to recycle the oxidant liquid.

Example 17

Referring to fig. 18, examples 1-14 are repeated except that: in order to reduce the corrosion rate of the produced liquid pipeline, in step 1), firstly, an oxidant or an oxidant liquid with the content of more than 0.001% or/and alkali is added into the produced liquid of the liquid outlet pipeline 302 by using a medicine adding pipeline 1800, so that hydrogen sulfide and/or odorous substances in the produced liquid are oxidized or/and generate a chemical reaction, and a produced liquid mixture containing sulfur or/and solid is formed; then, separating sulfur and solid matters in the produced liquid mixture by using solid-liquid separation equipment 1801 for further treatment; then the produced liquid with separated sulfur and solid enters a produced liquid pipeline 107 so as to enter a sewage treatment plant 108 for further treatment.

Known from the knowledge in the art: dissolving hydrogen sulfide in the sewage to form a hydrogen sulfuric acid corrosion pipeline; the alkali can effectively absorb hydrogen sulfide and can perform a neutralization reaction with the hydrosulfuric acid.

The indoor experiment shows that: taking a gas field of a big cattle as an example, sodium hydroxide and soda ash are added into produced liquid of the gas field to generate precipitates, and the precipitates can be separated by using filter paper.

The indoor experiment shows that: taking the produced fluid of a sulfur-containing gas well in a gas field of a big cattle as an example, adding hydrogen peroxide with the content of 3% into the produced fluid with the hydrogen sulfide content of the gas field of 2000mg/L, and adding manganese sand for slow catalytic oxidation, so that the hydrogen sulfide content of the produced fluid can be reduced to 2 mg/L; further experiments show that: firstly, adding hydrogen peroxide with the content of 2% into produced liquid with the hydrogen sulfide content of the gas field of 2000mg/L, then adjusting the pH value of the produced liquid to 8.5 by using 20% sodium hydroxide aqueous solution for slow catalytic oxidation, and reducing the hydrogen sulfide content of the produced liquid to 1 mg/L.

Example 18

Referring to fig. 19, examples 1-14 are repeated except that: in order to reduce the consumption of the oxidant by the reducing solid and reduce the dosing cost, in step 1), the solid in the produced liquid is separated by a solid-liquid separation device 1900 for further treatment; then adding an oxidant or oxidant liquid with the content of more than 0.001% or/and alkali into the produced liquid with the solid content separated in the pipeline 1901 by using a medicine adding pipeline 1800, so that hydrogen sulfide and/or odorous substances in the produced liquid are oxidized or/and generate chemical reaction to form a produced liquid mixture containing sulfur or/and the solid content; then, separating sulfur and solid matters in the produced liquid mixture by using solid-liquid separation equipment 1801 for further treatment; then the produced liquid with separated sulfur and solid enters a produced liquid pipeline 107 so as to enter a sewage treatment plant 108 for further treatment.

Example 19

Referring to fig. 20, example 17 is repeated with the following differences: in order to fully oxidize the hydrogen sulfide and/or the odorous substances and reduce the dosing cost, in the step 1), firstly, an oxidant or an oxidant aqueous solution with the content of more than 0.001% or/and alkali is added into the produced liquid of the liquid outlet pipeline 302 by using a dosing pipeline 1800 and enters a closed reaction vessel (or a static mixer) 2000, so that the hydrogen sulfide and/or the odorous substances in the produced liquid are fully oxidized or/and generate a chemical reaction to form a produced liquid mixture containing sulfur or/and solid matters; then, separating sulfur and solid matters in the produced liquid mixture by using solid-liquid separation equipment 1801 for further treatment; then the produced liquid with separated sulfur and solid enters a produced liquid pipeline 107 so as to enter a sewage treatment plant 108 for further treatment.

Preferably, the static mixer 2000 refers to any one of a packing static mixer, a labyrinth static mixer, a vertical static mixer and a horizontal static mixer, or any combination of any two or more thereof.

Example 20

Referring to fig. 21, example 18 is repeated except that: in order to sufficiently oxidize hydrogen sulfide and/or odorous substances and reduce the dosing cost, in the step 1), solid matters in produced liquid are separated by a solid-liquid separation device 1900 for further treatment; then adding an oxidant or oxidant liquid with the content of more than 0.001% or/and alkali into the produced liquid with the solid content separated in the pipeline 1901 by using a medicine adding pipeline 1800, and enabling the produced liquid to enter a closed reaction container (or a static mixer) 2000 to oxidize hydrogen sulfide and/or odorous substances in the produced liquid or/and generate a chemical reaction so as to form a produced liquid mixture containing sulfur or/and solid content; then, separating sulfur and solid matters in the produced liquid mixture by using solid-liquid separation equipment 1801 for further treatment; then the produced liquid with separated sulfur and solid enters a produced liquid pipeline 107 so as to enter a sewage treatment plant 108 for further treatment.

Example 21

Referring to fig. 22, a local area type natural gas desulfurization method includes the following steps:

1) gas-liquid mixture produced by the gas well 100 enters the header 301 through the valve 101 and the gas collecting pipeline 102, and gas-liquid mixture produced by the gas well 308 enters the header 301 through the valve 309 and the gas collecting pipeline 310, so that the gas-liquid mixture produced by different gas wells can be collected into the header 301; then the gas-liquid mixture of the collecting pipe 301 enters a gas-liquid separator 300 to be separated into natural gas and produced liquid, and then the produced liquid enters the truck tank car 201 through a liquid outlet pipeline 302 and a loading pipe 2200; then the produced liquid is sent to a sewage treatment plant 108 for further treatment through the truck tank car 201 and a unloading pipe 2201;

3) then the solid-liquid mixture is separated from the natural gas by a gas-liquid separator (or tower type closed container) 305 and enters a solid-liquid outlet pipeline 307 for further treatment, and the natural gas after the solid-liquid mixture is separated enters the interstation pipeline 104 through a natural gas outlet pipeline 306.

Example 22

Referring to fig. 23, example 21 is repeated except that: in order to simplify the process flow and facilitate management, in step 3), the gas-liquid separator (or tower-type closed container) 305 separates the solid-liquid mixture from the natural gas, and the mixture enters the solid-liquid outlet pipeline 307 for further treatment, and then the natural gas after separation of the solid-liquid mixture enters the inlet pipeline 601 of the purification device 600 through the natural gas outlet pipeline 306, so as to enter the purification device 600 for further treatment and then enter the purified natural gas (or dry gas) pipeline 602.

Example 23

Referring to fig. 24, example 21 is repeated except that: in order to simplify the process flow and facilitate management, in step 1), a gas-liquid mixture produced by the gas well 100 enters the gas-liquid separator 300 through the valve 101 and the gas collecting pipeline 102 to be separated into natural gas and produced liquid, and then the produced liquid enters the tank truck 201 through the liquid outlet pipeline 302 and the loading pipe 2200; then the produced liquid is sent to a sewage treatment plant 108 for further treatment through the truck tank car 201 and a unloading pipe 2201;

in step 3), the solid-liquid mixture is separated from the natural gas by a gas-liquid separator (or tower-type closed container) 305 and enters a solid-liquid outlet pipeline 307 for further treatment, and the natural gas after the solid-liquid mixture is separated enters the interstation pipeline 104 through a natural gas outlet pipeline 306.

Example 24

Referring to fig. 25, examples 21, 23 are repeated except that: in order to simplify the process flow and facilitate management, in step 3), the gas-liquid separator (or tower-type closed container) 305 separates the solid-liquid mixture from the natural gas, and the mixture enters the solid-liquid outlet pipeline 307 for further treatment, and then the natural gas after separation of the solid-liquid mixture enters the inlet pipeline 601 of the purification device 600 through the natural gas outlet pipeline 306, so as to enter the purification device 600 for further treatment and then enter the purified natural gas (or dry gas) pipeline 602.

Example 25

Referring to fig. 26, examples 21-24 were repeated except that: in order to prevent the produced liquid from volatilizing (or separating out) hydrogen sulfide to pollute the atmosphere, in step 1), firstly, adding an oxidant or an oxidant aqueous solution with the content of more than 0.001% or/and alkali into the produced liquid of the liquid outlet pipeline 302 by using a medicine feeding pipeline 1800, so that the hydrogen sulfide and/or odorous substances in the produced liquid are oxidized or/and generate chemical reaction to form a produced liquid mixture containing sulfur or/and solid matters; then the produced liquid mixture is loaded into the truck tank 201 by the loading pipe 2200; then the produced liquid mixture is sent to a sewage treatment plant 108 for further treatment through the truck 201 and the unloading pipe 2201.

Example 26

Referring to fig. 27, examples 21-24 were repeated except that: in order to better prevent the produced liquid from volatilizing (or separating out) hydrogen sulfide to pollute the atmosphere, in the step 1), firstly, an oxidant or an oxidant aqueous solution with the content of more than 0.001% or/and alkali is added into the produced liquid of the liquid outlet pipeline 302 by using a medicine adding pipeline 1800 and enters a closed reaction container (or a static mixer) 2000, so that the hydrogen sulfide and/or odorous substances in the produced liquid are fully oxidized or/and generate chemical reaction to form a produced liquid mixture containing sulfur or/and solid matters; then the produced liquid mixture is loaded into the truck tank 201 by the loading pipe 2200; then the produced liquid mixture is sent to a sewage treatment plant 108 for further treatment through the truck 201 and the unloading pipe 2201.

Example 27

Referring to fig. 28, examples 21-26 were repeated except that: in order to prevent the mixture from blocking pipeline equipment and pipeline valves of the automobile tank car, in the step 1), firstly, an oxidant or an oxidant water solution with the content of more than 0.001% or/and alkali is added into the produced liquid of the liquid outlet pipeline 302 by using a medicine feeding pipeline 1800, so that hydrogen sulfide and/or odor substances in the produced liquid are oxidized or/and generate a chemical reaction, and a produced liquid mixture containing sulfur or/and solid is formed; then, separating sulfur and solid matters in the produced liquid mixture by using solid-liquid separation equipment 1801 for further treatment; then the produced liquid after separating sulfur and solid is loaded into the tank car 201 by the loading pipe 2200; then the produced liquid after the sulfur and the solid are separated is sent to a sewage treatment plant 108 for further treatment through the tank car 201 and the unloading pipe 2201.

Example 28

Referring to fig. 29, a local area type natural gas desulfurization method includes the following steps:

1) gas-liquid mixture produced by the gas well 100 enters the header 301 through the valve 101 and the gas collecting pipeline 102, and gas-liquid mixture produced by the gas well 308 enters the header 301 through the valve 309 and the gas collecting pipeline 310, so that the gas-liquid mixture produced by different gas wells can be collected into the header 301; then the gas-liquid mixture in the collecting pipe 301 enters a gas-liquid separator 300 to be separated into natural gas and produced liquid; then the produced liquid is sent to an evaporation system 2900 through a liquid outlet pipeline 302 to evaporate the moisture in the produced liquid; then carrying out further treatment on the residual concentrated solution or residue of the extracted liquid after water evaporation;

Example 29

Referring to fig. 30, examples 1-14 are repeated except that: in order to prevent the produced liquid from volatilizing (or separating out) hydrogen sulfide to pollute the atmosphere, in step 1), firstly, adding an oxidant or an oxidant aqueous solution with the content of more than 0.001% or/and alkali into the produced liquid of the liquid outlet pipeline 302 by using a medicine feeding pipeline 1800, so that the hydrogen sulfide and/or odorous substances in the produced liquid are fully oxidized or/and chemically reacted to form a produced liquid mixture containing sulfur or/and solid matters; the water in the production fluid mixture is then evaporated with the evaporation system 2900.

Example 30

Referring to fig. 31, examples 1-14 are repeated except that: in order to prevent the produced liquid from volatilizing (or separating out) hydrogen sulfide to pollute the atmosphere, in step 1), firstly, adding an oxidant or an oxidant aqueous solution with the content of more than 0.001% or/and alkali into the produced liquid of a liquid outlet pipeline 302 by using a medicine adding pipeline 1800, and enabling the hydrogen sulfide and/or odorous substances in the produced liquid to be fully oxidized or/and generate a chemical reaction to form a produced liquid mixture containing sulfur or/and solid matters; the water in the production fluid mixture is then evaporated with the evaporation system 2900.

Example 31

Examples 1, 5-20, 27-21, 28-30 were repeated with the following differences: the oxidant is any one of pentavalent vanadium compound, chlorate, perchlorate, permanganate, peroxide, hydrogen peroxide, fluorine, chlorine, bromine, iodine, ferric salt, cupric salt, trivalent cupric salt, tetravalent cupric salt, pentavalent vanadium salt, complex iron and chelated iron or a mixture of more than two of the above materials which do not produce chemical reaction after being mixed in any proportion.

Known from the knowledge in the art: the complex iron is also called ferric iron complex and ferric iron coordination compound; chelated iron is also called ferric mastiff compound; ferric chloride is a common ferric salt, and is dissolved in water.

Example 32

Examples 1, 5-20, 27-21, 28-30 were repeated with the following differences: the oxidant liquid is a mixed solution of methanol and water of an oxidant in any proportion.

Known from the knowledge in the art: water and methanol are mutually soluble, and the methanol is applied to a large scale in the current gas field to inhibit natural gas hydrate and prevent freezing and blocking.

Indoor tests show that: hydrogen peroxide, ferric trichloride aqueous solution, sodium hypochlorite aqueous solution and ferric iron complex are all dissolved in methanol or ethanol.

Example 33

Examples 1, 5-20, 27-21, 28-30 were repeated with the following differences: the oxidant liquid is a methanol solution of an oxidant.

Example 34

Examples 1, 5-20, 27-21, 28-30 were repeated with the following differences: the oxidant liquid is an aqueous solution or/and an alcoholic solution of a ferric complex with a pH value of more than 7.5.

Indoor tests show that: the ferric complex aqueous solution with the pH of 10 does not demix and precipitate after standing for 48 hours indoors, and has good stability; further comparative experiments show that: the decomposition of the hydrogen peroxide is accelerated when the pH value is 10, bubbles are generated, the stability is poor, and the precipitation is generated when the pH value of the ferric trichloride aqueous solution is adjusted to 8 by using sodium carbonate or sodium hydroxide.

Example 35

Examples 1, 5-20, 27-21, 28-30 were repeated with the following differences: in order to prevent the winter icing, the oxidant aqueous solution contains 5-60% of organic acid salt.

Known from the knowledge in the art: gas wells are normally produced in winter; potassium formate belongs to organic acid salts.

Indoor tests show that: in a 10% sodium hypochlorite aqueous solution, 20% hydrogen peroxide and 15% ferric iron complex aqueous solution, the freezing point of 60% potassium formate is lower than-50 ℃, the freezing point of 40% potassium formate is lower than-30 ℃, and the freezing point of 5% potassium formate is lower than-4 ℃.

The terms "upper," "lower," "left," "right," and the like as used herein to describe the orientation of the components are based on the orientation as shown in the figures of the drawings for convenience of description, and in actual systems, the orientation may vary depending on the manner in which the system is arranged.

It should be understood that the above-described embodiments of the present invention are merely examples for clearly illustrating the present invention, and are not intended to limit the embodiments of the present invention. Other variations and modifications will be apparent to persons skilled in the art in light of the above description. Not all embodiments are exhaustive. All obvious changes and modifications which are obvious to the technical scheme of the invention are covered by the protection scope of the invention.

Claims

1. A local area type natural gas desulfurization method is characterized by comprising the following steps:

2. The method of claim 1, wherein the desulfurization of natural gas comprises:

in the step 2), adding oxidant liquid with the content of more than 0.001% into the upper part of the packed tower, enabling the oxidant liquid to flow in the packing from top to bottom, and simultaneously enabling natural gas to enter the lower part of the packed tower and enabling the natural gas to flow in the packing from bottom to top, so that hydrogen sulfide and/or odorous substances in the natural gas are fully contacted with the oxidant liquid, mixed and oxidized to form a sulfur-containing solid-liquid mixture;

in step 3), the solid-liquid mixture enters the lower part or the bottom of the packed tower and then leaves the packed tower from the lower part or the bottom of the packed tower for further treatment.

3. The method of claim 1, wherein the desulfurization of natural gas comprises:

in the step 2), adding oxidant liquid with the content of more than 0.001% into the upper part of the plate tower, enabling the oxidant liquid to flow from top to bottom, and simultaneously enabling natural gas to enter the lower part of the plate tower and enabling the natural gas to flow from bottom to top, so that hydrogen sulfide and/or odorous substances in the natural gas are fully contacted with the oxidant liquid, mixed and oxidized to form a sulfur-containing solid-liquid mixture;

in step 3), the solid-liquid mixture enters the lower part or the bottom of the plate tower and then leaves the plate tower from the lower part or the bottom of the plate tower for further treatment.

4. The method of claim 1, wherein the desulfurization of natural gas comprises:

in the step 2), adding oxidant liquid with the content of more than 0.001% into the upper part of the spray tower, enabling the oxidant liquid to flow or drip from top to bottom, and simultaneously enabling natural gas to enter the lower part of the spray tower and enabling the natural gas to flow from bottom to top, so that hydrogen sulfide and/or odorous substances in the natural gas are fully contacted with the oxidant liquid, mixed and oxidized to form a sulfur-containing solid-liquid mixture;

in the step 3), the solid-liquid mixture enters the lower part or the bottom of the spray tower and then leaves the spray tower from the lower part or the bottom of the spray tower for further treatment.

5. The method of claim 1, wherein the desulfurization of natural gas comprises:

in the step 2), adding oxidant liquid with the content of more than 0.001% into a closed container, enabling the liquid level height of the oxidant liquid to be more than 5cm and lower than the top of the closed container, then enabling natural gas to enter the lower part of the oxidant liquid and enabling the natural gas to flow from bottom to top in a bubble mode, and enabling hydrogen sulfide and/or odorous substances in the natural gas to be fully contacted with the oxidant liquid, mixed and oxidized to form a sulfur-containing solid-liquid mixture;

in step 3), the solid-liquid mixture leaves the closed container from the bottom or the lower part of the closed container for further treatment.

6. The method of claim 1, wherein the desulfurization of natural gas comprises:

in the step 2), adding oxidant liquid with the content of more than 0.001% into the natural gas, and then feeding the natural gas into a static mixer along with the natural gas to be continuously contacted and mixed with the natural gas, so that hydrogen sulfide and/or odorous substances in the natural gas are fully contacted and mixed with the oxidant liquid to be oxidized, and a sulfur-containing solid-liquid mixture is formed; in the step 3), the solid-liquid mixture enters a gas-liquid separator or a tower type closed container along with the natural gas, and then the solid-liquid mixture is separated from the natural gas by the gas-liquid separator or the tower type closed container for further treatment.

7. The method of claim 6, wherein: the static mixer refers to any one of a packing type static mixer, a labyrinth type static mixer, a vertical static mixer and a horizontal static mixer or any combination of more than two of the packing type static mixer, the labyrinth type static mixer, the vertical static mixer and the horizontal static mixer.

8. The method of claim 1, wherein the desulfurization of natural gas comprises:

in the step 2), the oxidant liquid with the content of more than 0.001 percent and the natural gas enter the bottom of a static mixer filled with the filler, and are continuously contacted and mixed by the filler;

and 3) allowing the solid-liquid mixture and the natural gas to enter a gas-liquid separator or a tower type closed container from the top of the static mixer.

9. The method of claim 1, wherein the desulfurization of natural gas comprises:

in the step 2, the oxidant liquid with the content of more than 0.001 percent enters an atomizer to be atomized into tiny liquid drops, and the tiny liquid drops are contacted and mixed with the natural gas, so that hydrogen sulfide and/or odorous substances in the natural gas are fully contacted and mixed with the oxidant liquid to be oxidized, and a sulfur-containing solid-liquid mixture is formed;

in the step 3), the solid-liquid mixture enters a gas-liquid separator or a tower type closed container along with the natural gas, and then the solid-liquid mixture is separated from the natural gas by the gas-liquid separator or the tower type closed container for further treatment.

10. The method of claim 9, wherein the desulfurization of natural gas comprises:

the atomizer is a device capable of making liquid into micro-droplets or liquid drops, and can be any one of a mechanical atomizer, an ultrasonic atomizer and an electric atomizer or any combination of any two or more of the above.

11. The method of claim 1, wherein the desulfurization of natural gas comprises:

in the step 3), the solid-liquid mixture is sent to a regeneration system to be regenerated into suspension with the oxidant content being more than 0.001 percent; then sending the oxidant suspension into a solid-liquid separation system to be separated into sulfur paste (or sulfur solid) and oxidant liquid with the content of more than 0.001 percent, further recycling or harmlessly treating the sulfur paste (or sulfur solid), and sending the oxidant liquid with the content of more than 0.001 percent into a medicament tank; then adding the oxidant liquid with the content of more than 0.001% into the natural gas so as to recycle the oxidant liquid.

12. The method of claim 1, wherein the desulfurization of natural gas comprises:

in the step 3), the solid-liquid mixture is sent into a regeneration system comprising a shell, a medicine outlet pipeline, a sulfur foam outlet flow passage, an air outlet pipe and an air inlet pipe, so that the liquid in the solid-liquid mixture is regenerated into oxidant liquid with the oxidant content of more than 0.001%, the solid and the sulfur in the solid-liquid mixture are floated to the liquid level by air bubbles to form sulfur foam and oxidant liquid with the oxidant content of more than 0.001%, and the oxidant liquid with the oxidant content of more than 0.001% is sent into a medicament tank; then the sulfur foam enters a solid-liquid separation system and is separated into sulfur paste (or sulfur solid) and oxidant liquid with the content of more than 0.001 percent, the sulfur paste (or sulfur solid) is further recycled or treated in a harmless way, and the oxidant liquid with the content of more than 0.001 percent is sent into a medicament tank; then adding the oxidant liquid with the content of more than 0.001 percent in the medicament tank into the natural gas so as to recycle the oxidant liquid.

13. The method for desulfurizing a natural gas according to claim 11 or 12, wherein: in step 3), a foaming agent or/and a flocculating agent is added into the solid-liquid mixture or the regeneration system.

14. The method of claim 12, wherein:

the air inlet pipe is positioned at the bottom of the solid-liquid mixture and is provided with an air distribution device.

15. The method of claim 1, wherein the desulfurization of natural gas comprises:

in the step 3), the solid-liquid mixture is sent to a solid-liquid separation system to be separated into sulfur paste (or sulfur solid) and liquid, the sulfur paste (or sulfur solid) is further recycled or subjected to harmless treatment, and the liquid is sent to a regeneration system to be regenerated into oxidant liquid with the oxidant content of more than 0.001 percent; then adding the oxidant liquid with the content of more than 0.001% into the natural gas so as to recycle the oxidant liquid.

16. The method of claim 1, wherein the desulfurization of natural gas comprises:

in the step 1), firstly, adding an oxidant or oxidant liquid with the content of more than 0.001% or/and alkali into the separated produced liquid to oxidize or/and generate chemical reaction on hydrogen sulfide and/or odorous substances in the produced liquid to form a produced liquid mixture containing sulfur or/and solids; then separating out sulfur and solid in the produced liquid mixture for further treatment; then the produced liquid with separated sulfur and solid enters a sewage treatment plant for further treatment.

17. The method of claim 1, wherein the desulfurization of natural gas comprises:

in the step 1), solid matters in the produced liquid are separated and further processed; then adding an oxidant or a liquid or/and alkali with the oxidant content being more than 0.001% into the produced liquid after solid separation, so that hydrogen sulfide and/or odorous substances in the produced liquid are oxidized or/and generate chemical reaction, and a produced liquid mixture containing sulfur or/and solid is formed; then separating out sulfur and solid in the produced liquid mixture for further treatment; then the produced liquid with separated sulfur and solid enters a sewage treatment plant for further treatment.

18. The method of claim 1, wherein the desulfurization of natural gas comprises:

in the step 1), firstly, adding an oxidant or an oxidant aqueous solution with the content of more than 0.001% or/and alkali into the produced liquid, and feeding the produced liquid into a closed reaction vessel or a static mixer along with the produced liquid to ensure that hydrogen sulfide and/or odorous substances in the produced liquid are fully oxidized or/and generate chemical reaction to form a produced liquid mixture containing sulfur or/and solid; then separating out sulfur and solid in the produced liquid mixture for further treatment; then the produced liquid with separated sulfur and solid enters a sewage treatment plant for further treatment.

19. The method of claim 1, wherein the desulfurization of natural gas comprises: in the step 1), solid matters in the produced liquid are separated and further processed; then adding an oxidant or an oxidant aqueous solution with the content of more than 0.001% or/and alkali into the produced liquid and enabling the produced liquid to enter a closed reaction vessel or a static mixer so as to oxidize hydrogen sulfide and/or odorous substances in the produced liquid or/and generate a chemical reaction to form a produced liquid mixture containing sulfur or/and solids; then separating out sulfur and solid in the produced liquid mixture for further treatment; then the produced liquid with separated sulfur and solid enters a sewage treatment plant for further treatment.

20. The method of claim 1, wherein the desulfurization of natural gas comprises: in the step 3), the solid-liquid mixture is firstly transported to a regeneration place by a vehicle, and then the solid-liquid mixture is sent to a regeneration system to be regenerated into oxidant suspension with the oxidant content being more than 0.001 percent; then sending the oxidant suspension into a solid-liquid separation system to be separated into sulfur paste (or sulfur solid) and oxidant liquid with the content of more than 0.001%, and further recycling or harmlessly treating the separated sulfur paste (or sulfur solid); then adding the separated oxidant liquid with the content of more than 0.001% into the natural gas so as to recycle the oxidant liquid.

21. A local area type natural gas desulfurization method is characterized by comprising the following steps:

22. The method of claim 21, wherein: in the step 1), oxidizing or/and carrying out chemical reaction on hydrogen sulfide and/or odorous substances in produced liquid to form a produced liquid mixture containing sulfur or/and solids in an oxidant aqueous solution or/and alkali produced liquid with the content of more than 0.001%; and then the produced liquid mixture is sent to a sewage treatment plant for further treatment by a tank truck.

23. The method of claim 21, wherein: in the step 1), firstly, adding an oxidant or an oxidant aqueous solution with the content of more than 0.001% or/and alkali into the produced liquid, and enabling the produced liquid to enter a closed reaction vessel or a static mixer so as to fully oxidize hydrogen sulfide and/or odorous substances in the produced liquid or/and generate a chemical reaction to form a produced liquid mixture containing sulfur or/and solid matters; and then the produced liquid mixture is sent to a sewage treatment plant for further treatment by a tank truck.

24. The method of claim 21, wherein: in the step 1), firstly, adding an oxidant or an oxidant aqueous solution with the content of more than 0.001% or/and alkali into the produced liquid to oxidize hydrogen sulfide and/or odorous substances in the produced liquid or/and generate a chemical reaction to form a produced liquid mixture containing sulfur or/and solids; then, separating sulfur and solid matters in the produced liquid mixture by using solid-liquid separation equipment for further treatment; then the produced liquid after separating out sulfur and solid is sent to a sewage treatment plant for further treatment by a tank car.

25. A local area type natural gas desulfurization method is characterized by comprising the following steps:

26. The method of claim 25, wherein: in the step 1), firstly, adding an oxidant or an oxidant aqueous solution with the content of more than 0.001% or/and alkali into the produced liquid to fully oxidize hydrogen sulfide and/or odorous substances in the produced liquid or/and generate chemical reaction to form a produced liquid mixture containing sulfur or/and solids; then evaporating the water in the produced liquid mixture by an evaporation method; the concentrate or residue of the produced fluid mixture remaining after evaporation of water is then transported away for further processing.

27. The method of claim 25, wherein: in the step 1), firstly, adding an oxidant or an oxidant aqueous solution with the content of more than 0.001% or/and alkali into the produced liquid, and enabling the produced liquid to enter a closed reaction vessel or a static mixer so as to fully oxidize hydrogen sulfide and/or odorous substances in the produced liquid or/and generate a chemical reaction to form a produced liquid mixture containing sulfur or/and solid matters; then evaporating the water in the produced liquid mixture by an evaporation method; the concentrate or residue of the produced fluid mixture remaining after evaporation of water is then transported away for further processing.

28. The method for the desulfurization of natural gas according to claims 25 to 27, wherein: the evaporation method refers to any one of heating evaporation and ventilation evaporation or any combination of the heating evaporation and the ventilation evaporation.

29. The method for desulfurizing a natural gas according to any one of claims 1 to 6, 8 to 9, 11 to 12, 15 to 20, 21 to 24, and 25 to 27, wherein:

the oxidant is any one of chlorate, perchlorate, permanganate, peroxide, hydrogen peroxide, fluorine, chlorine, bromine, iodine, ferric salt, cupric salt, trivalent cupric salt, tetravalent cupric salt, complex iron and chelated iron or a mixture of more than two of the above substances which do not generate chemical reaction after being mixed in any proportion.

30. The method for desulfurizing a natural gas according to any one of claims 1 to 6, 8 to 9, 11 to 12, 15 to 20, 21 to 24, and 25 to 27, wherein: the oxidant liquid is a mixed solution of methanol and water of an oxidant in any proportion.

31. The method for desulfurizing a natural gas according to any one of claims 1 to 6, 8 to 9, 11 to 12, 15 to 20, 21 to 24, and 25 to 27, wherein: the oxidant liquid is a methanol solution of an oxidant.

32. The method for desulfurizing a natural gas according to any one of claims 1 to 6, 8 to 9, 11 to 12, 15 to 20, 21 to 24, and 25 to 27, wherein: the oxidant liquid is an aqueous solution or/and an alcoholic solution of a ferric complex with a pH value of more than 7.5.

33. The method for desulfurizing a natural gas according to any one of claims 1 to 6, 8 to 9, 11 to 12, 15 to 20, 21 to 24, and 25 to 27, wherein: the oxidant liquid contains 5-60% of organic acid salt.