Method for removing hydrogen sulfide in natural gas

A hydrogen sulfide and natural gas technology, applied in chemical instruments and methods, separation methods, gas fuels, etc., can solve problems such as equipment corrosion, alcohol amine solvent loss, large floor space of absorption towers and desorption towers, etc., to reduce land occupation Area, the effect of saving land

Inactive Publication Date: 2017-04-05
CHINA PETROLEUM & CHEM CORP +1
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  • Summary
  • Abstract
  • Description
  • Claims
  • Application Information

AI Technical Summary

Problems solved by technology

In addition, the loss of alcohol amine solvent, foaming and degradation, and equipment corrosion caused by solvent degradation are the main problems currently exist

Method used

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  • Method for removing hydrogen sulfide in natural gas

Examples

Experimental program
Comparison scheme
Effect test

Embodiment 1

[0058] The volume content of hydrogen sulfide in a certain natural gas is 10%.

[0059] The treatment steps are as follows: under the pressure of 0.1MPa, press natural gas containing hydrogen sulfide into the shell side of a section of polypropylene hollow fiber hydrophobic membrane module with a pore size of 0.2μm, and use cold water at a temperature of 5°C as the absorbing liquid to make it in the hollow The tube side of the fiber hydrophobic membrane module is the reverse flow of the hollow fiber membrane hole and the natural gas containing hydrogen sulfide. The hydrogen sulfide in the natural gas permeates through the membrane and enters the water absorption liquid. The flow rate of the cold water in the tube side is 0.5m / s. After the sulfur-containing effluent of the hydrophobic membrane is heat-exchanged by the heat exchanger, it is heated to 45°C by a pipeline heater, and then flows into the membrane pores of the two-stage polypropylene hollow fiber hydrophobic membrane ...

Embodiment 2

[0064] The volume content of hydrogen sulfide in a certain natural gas is 12%.

[0065] The treatment steps are as follows: under the pressure of 0.2MPa, press natural gas containing hydrogen sulfide into the shell side of a section of polypropylene hollow fiber hydrophobic membrane module with a pore size of 0.15μm, and use cold water at a temperature of 15°C as the absorbing liquid to make it in the hollow The tube side of the fiber hydrophobic membrane module is the reverse flow of the hollow fiber membrane hole and the natural gas containing hydrogen sulfide. The hydrogen sulfide in the natural gas permeates through the membrane and enters the water absorption liquid. The flow rate of the cold water in the tube side is 1.0m / s. After the sulfur-containing effluent of the hydrophobic membrane is heat-exchanged by the heat exchanger, it is heated to 42°C by a pipeline heater, and then flows into the membrane pores of the two-stage polypropylene hollow fiber hydrophobic membran...

Embodiment 3

[0070] The volume content of hydrogen sulfide in a certain natural gas is 15%.

[0071] The treatment steps are as follows: under the pressure of 0.3 MPa, the natural gas containing hydrogen sulfide is pressed into the shell side of a section of polypropylene hollow fiber hydrophobic membrane module with a pore size of 0.1 μm, and cold water at a temperature of 10 ° C is used as the absorption liquid to make it in the hollow The tube side of the fiber hydrophobic membrane module is the reverse flow of the hollow fiber membrane hole and the natural gas containing hydrogen sulfide. The hydrogen sulfide in the natural gas permeates through the membrane and enters the water absorption liquid. The flow rate of the cold water in the tube side is 0.7m / s. The sulfur-containing effluent from the hydrophobic membrane is heated to 40°C by a pipeline heater after being heat-exchanged by a heat exchanger, and then flows into the membrane pores of the two-stage polypropylene hollow fiber hyd...

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Abstract

The invention relates to a method for removing hydrogen sulfide in natural gas. The method comprises the following steps: 1) using difference of different gases in water, taking water as absorption liquid, employing a first segment of a hydrophobic membrane for absorbing hydrogen sulfide in the sulfur-containing natural gas to water at the other side of the membrane, forming a sulfur-containing effluent; 2) employing a second segment of the hydrophobic membrane, pumping the negative pressure at membrane permeation side of the second segment of the hydrophobic membrane, extracting the hydrogen sulfide in the sulfur-containing effluent through the second segment of the hydrophobic membrane to the membrane permeation side, and collecting the material to remove the hydrogen sulfide in the natural gas. The method employs water as the absorption liquid, which is environmentally friendly, the problems of equipment corrosion due to solvent loss, foaming and degradation as well as solvent degradation by alkylol amine absorption in a natural gas chemical absorption process desulphurization technology can be solved, land occupation area of equipment is reduced, land occupation is saved, skid-mounted and modularization processing can be realized for the place-limited region.

Description

technical field [0001] The invention relates to the field of natural gas purification, in particular to a method for removing hydrogen sulfide in natural gas. In particular, it refers to the method of removing hydrogen sulfide from natural gas by using membrane separation technology. Background technique [0002] With the development of the natural gas industry, high-sulfur gas fields continue to appear, and natural gas contains a large amount of H 2 S gas, due to H 2 When S gas encounters condensed water, it will not only cause overall corrosion of pipes and containers, but also cause sulfide stress corrosion cracking. In addition, CO 2 If the content is too high, the calorific value of natural gas will not meet the requirements. Therefore, all countries have corresponding purification standards for the quality of natural gas. Natural gas purification processes generally include natural gas desulfurization, decarbonization, dehydration and other processes. As far as p...

Claims

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Application Information

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IPC IPC(8): B01D53/14B01D53/22C10L3/10
Inventor 张新妙郭智杨永强彭海珠
Owner CHINA PETROLEUM & CHEM CORP
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