Method of acid gas treatment for injection into formation through injector

FIELD: oil and gas industry.

SUBSTANCE: invention is related to oil and gas industry and namely to treatment methods of an acid gas containing hydrogen sulphide and carbon dioxide for injection into a formation through an injector. The concept of the invention is as follows: according to the method treatment of the acid gas for injection into the formation through the injector is made by the acid gas delivery to several compression and cooling stages at a temperature of 40÷60°C, drying of the compressed acid gas by glycol at a compressive pressure and temperature of 45÷65°C, transition of the dried gas into liquid state by further compression and cooling up to a temperature of 40÷65°C. At that before delivery to the compression stage acid gases are mixed with a liquefied gas C3-C5 or natural gasoline in quantity of 10÷40% by weight. Compression-cooling and drying of the acid gas is made at a pressure up to 0.4÷0.6MPa and its transition to liquid state is made at a pressure up to 0.8÷4.0MPa.

EFFECT: reduction of power consumption, reduction of gas hydrate formation risk, decrease in the number of compression and cooling stages for acid gases and utilisation of associated liquefied gases and natural gasoline containing hydrogen sulphide.

2 ex, 1 dwg

 

The invention relates to the oil and gas industry, and in particular to methods of preparation of acid gas containing hydrogen sulfide and carbon dioxide for injection into the formation via the injection well for the purpose of their disposal.

A known method of preparation of the acid gas comprising hydrogen sulfide and carbon dioxide for injection into the formation via the injection well in a mixture with water, which is in compression, acid gas compressors in several stages of compression to pressure 4,55÷14,0 MPa (depending on the composition of the acid gas with intermediate cooling acid gas after each stage cooling with getting sour gas in liquid form, which is at the same pressure is mixed with water having a pH of at least 7.5, and served on the cylinder and injection wells for the injection pump into the reservoir (U.S. Pat. USA, No. 6149344, NCI 405/128, publ. 21.11.2000).

The disadvantage of this method are considerable expenditure of energy required for compression acid gas compressor to a pressure of liquefaction, the corrosion of the equipment wet sour gas and increase the risk of formation of gas hydrates due to the high pressure compression acid gas.

The closest analogue to the present invention is a method of preparation of the acid gas to be injected into the formation via the injection well by filing an acidic gas in several stages

JUA is FL-cooling to pressure 2.5÷5.0 MPa and a temperature of 40-60°C, drying compressed gas glycol dehydration unit at the same pressure and a temperature of 45-65°C, transfer the drained gas into a liquid state by compressing to a pressure of 5.5÷10,0 MPa and cooling to a temperature of 40÷65°C and the injection of liquid acid gas into the formation via the injection well (U.S. Pat. RF, 2342525 IPC E21B 43/40, published 27.12. 2008).

The disadvantage of this method, taken as a prototype, is that there remains a need in significant energy costs associated with compressed gas sour gas compressor to pressure liquefaction, and increasing the content of carbon dioxide leads to a further increase in pressure required for liquefaction. The content of CO2in acid gas, which is obtained by amine treatment source of associated and natural gas, is determined by its content in these gases and may vary within considerable limits. The overwhelming content of carbon dioxide in the acid gas and the temperature of the compressed and dried sour gas 55-60°C by further compression acid gas according to the method, taken as a prototype, you cannot put it in the liquid state, because if the pressure at the same temperature and in the absence in the composition of the acid gas hydrocarbon components of LPG is its transition to a critical state, mine is the liquid state. Increased energy costs by a known method is also due to the energy costs for the recycling of glycol dehydration unit, in which the differential pressure between desorber and the absorber is up to 4 MPa and above. In addition, there is a risk of hydrate formation during compression acid gas to a pressure of liquefaction.

The objective of the invention is to reduce energy costs, reducing the risk of formation of gas hydrates, reducing the number of stages of compression-cooling acid gas removal and disposal of associated hydrogen sulfide-containing gases and gas gasoline.

The technical result that can be obtained by carrying out the method:

- reduction of energy costs for compression acid gas compressor, which is achieved by liquefying them at a lower pressure due to the introduction of the acid gas LPG C3-C5 and gas gasoline;

- reduce energy costs by recycling the glycol dehydration unit by carrying out drying at a lower pressure, which allows drying at a small pressure difference between the absorber and desorber, and leads to lower electricity for pumping glycol;

- reducing the risk of hydrate formation by reducing the pressure of the compression acid gas prior to liquefaction;

- disposal of contaminated acidic components of the liquefied gas and the gas is o gasoline by injection into a reservoir together with acidic gases.

This technical result is achieved by the method of preparation of the acid gas to be injected into the formation via the injection well by filing an acidic gas in multiple stages of compression and cooling at a temperature of 40÷60°C, drying the compressed acid gas glycol at a pressure of compression and the temperature of 45÷65°C, transfer the drained gas in the liquid state followed by compression and cooling it to a temperature of 40÷65°C and injection of liquid acid gas into the formation via the injection well, while the acidic gases before serving compression is mixed with liquefied gas C3-C5or gas gasoline, taken in an amount of 10÷40% by wt., moreover, the compression-cooling acid gas and the drying is performed at a pressure up to 0.4÷0.6 MPa, and a translation of it in the liquid state is carried out at a pressure of up to 0.8÷4.0 MPa.

The drawing shows a diagram of preparation of sour gas to be injected into the formation via the injection well.

The method is as follows.

Sour gas treatment unit source petroleum or natural gas from hydrogen sulphide and carbon dioxide (I) at a pressure of 0.05÷0.2 MPa serves on mixing with liquefied gas - a mixture of hydrocarbons C3-C5 or gas gasoline (II), then mixed stream is fed to the input of the compressor 1 compressor-cooling, in which the gas is compressed to a pressure of 0.4÷0.6 MPa. Next, the flow of compressed gas (III served in the fridge 2 (which may be in the form of an air cooler), in which it is cooled to a temperature of 40÷60°C, then cooled stream (IV) is sent to the separator 3.

In the separator 3, the cooled stream (IV) is separated into a gas phase - sour gas and condensate, with the sour gas stream (V) directed to the glycol dehydration in block 4, in which the gas is dried to a residual water content not more than 0.01 wt.%, and condensate (VI) is removed for recycling. The absorber unit 4 is irrigated with highly concentrated solution of triethylene glycol (TEG) (97,5÷of 99.5 wt.%). Dried sour gas (VII), containing liquefied gas or gasoline, with a temperature of 45÷65°C output from block 4 and is directed to the input of the compressor 7, where his win to pressure 0,8÷4.0 MPa, and compressed gas (VIII) is cooled in a water refrigerator or an air cooler 8 to a temperature of 40÷60°C. Under these conditions, the gas becomes a single-phase liquid state.

The cooled stream of liquid acid gas (IX) pump 9 is directed to injection into the formation through injection well (X).

Saturated water solution TAG, obtained by the dehydration of acid gas at a temperature of 45÷65°C derive from a bottom of the absorber drying unit 4 and is directed to capacity-expander, where the selection is physically absorbed in the TAG component acid gas, which recycle (XI) to the input of the compressor 1.

Water vapor (XII) is removed from the upper part of the regenerator unit ososki, cool in the refrigerator 5, and the cooled stream (XIII) served in the separator 6. The condensate (XIV) from the lower part of the separator 6 serves to mix with the condensate from the separator 3 and the combined stream (XV) sent for recycling. The gas phase from the upper portion of the separator 6 display and also sent for recycling (XVI).

The power savings of the proposed method is achieved by reducing the pressure of the acid gas liquefaction, which allows further compression acid gas prior to pressure injection (20÷24 MPa) into the reservoir in a liquid state with the use of the pump, which is more economical car than the compressor. The power savings can also be achieved by dehydration of gas glycol at a lower pressure.

Example 1. Sour gas installation amine scrubbing in the amount of 500 m3/h with a pressure of 0.05 MPa and a temperature of 40°C, mixed with the stream of liquefied gas. Sour gas contains 80% of hydrogen sulfide and 20% vol. carbon dioxide gas, and LPG consists of propane, butane and pentane in a ratio of 1:1:1 and its consumption is 330 m3/h Flow rate of the mixed gas - 830 m3/h, the content of components of liquefied gas is 39.8%. The mixed gas is then directed into the compressor, where the gas is compressed to a pressure of 0.4 MPa, and then cooled in a refrigerator to a temperature of 50°C, followed by the separation in the gas separa the ora of the principal amount of moisture in the form of condensate, which derive from the lower part of the separator in the amount of 33 kg/h To remove the remaining amount of water the gas phase from the upper part of the separator is sent to the absorber, irrigated with triethylene glycol. After the absorber, the moisture content in the gas having a temperature of 60°C is 0.01%. The compressed and dried so sour gas containing as a component of the liquefied gas, compressed by the compressor to the design pressure liquefaction of 0.8 MPa. Get the liquid in the number 1669.0 kg, which is cooled to 45°C and the pump serves to pump into the formation via the injection well.

Saving energy by reducing the pressure of liquefaction from 4.2 MPa prototype (for sour gas without mixing with liquefied gas) up to 0.8 MPa for the proposed method is 200 kWh per 1000 m3acid gas.

Example 2. Sour gas installation amine scrubbing in quantities of 1000 m3/h with a pressure of 0.08 MPa and a temperature of 45°C is mixed with the stream of liquefied gas. Sour gas contains 39% wt. hydrogen sulfide and 61% of carbon dioxide, and the ratio of propane, butane and pentane in liquefied gas are, respectively,

0,61:0,35:0.05, the consumption of it - 425 m3/h Flow rate of the mixed gas - 1425 m3/h, the content of components of liquefied gas to 29.8%. This gas is then compressed to a pressure of 0.6 MPa, cooled in a refrigerator at 5°C, followed by the separation in the gas separator of the principal amount of moisture in the form of condensate in the amount of 57 kg/h To remove the remaining amount of water the gas phase from the upper part of the separator is sent to the absorber, irrigated triethylene glycol. After the absorber, the moisture content in the gas having a temperature of 60°C is 0.01%. The compressed and dried so sour gas containing as a component of the liquefied gas, compressed by the compressor to the design pressure liquefaction of 3.8 MPa. Get the liquid in the number 2672.0 kg, which is cooled to 45°C and the pump serves to pump into the formation via the injection well.

The method of preparation of the acid gas to be injected into the formation via the injection well by filing an acidic gas in multiple stages of compression and cooling to a temperature of 40÷60°C, drying the compressed acid gas glycol at a pressure of compression and the temperature of 45÷65°C, transfer the drained gas in the liquid state followed by compression and cooling it to a temperature of 40÷65°C and injection of liquid acid gas into the formation via the injection well, wherein the acidic gases before serving compression is mixed with liquefied gas C3-C5or gas gasoline, taken in an amount of 10÷40% by wt., moreover, the compression-cooling acid gas and the drying is performed at a pressure up to 0.4÷0.6 MPa, and a translation of it in the liquid state is carried out at a pressure of up to 0.8÷4.0 MPa.



 

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3 cl, 2 tbl, 25 ex, 5 dwg

FIELD: process engineering.

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8 cl, 10 dwg

FIELD: treatment and stacking of domestic solid wastes.

SUBSTANCE: the invention is pertinent to the field of treatment and stacking of domestic solid wastes, in particular, to joint stacking of domestic solid waste products and the bioadditives produced on the basis of the settling sewage, the surplus active sludge of sewage treatment plants and the filling agents - composts from the factories for the domestic solid wastes processing. The technical result is an increased sedimentation of the placed domestic solid wastes at the optimal values of concentration of introduced bioadditives, decreased required useful area to process the domestic solid wastes and increased accuracy of determination of a time of the sedimentation process termination. The method includes introduction of the bioadditives produced on the base of a mix of sludge of waste waters of the sewage treatment plants and composts from a factory on processing of the domestic solid wastes. At introduction of bioadditives in amount of 5-7 % of the total mass of the placed waste products, the contamination of which by microflora - decomposer makes 108 - 1010 cells/g. Intensification of the process of decomposition of organic components of placed waste products takes place and due to that increased their sedimentation. At that the value of sedimentation of the layers of the placed waste products is determined by formula: , where Hsed - a value of sedimentation of layers of the placed domestic solid wastes, in meters; h - initial value of height of the placed domestic solid wastes, in meters; τ - time of sedimentation of layers of the placed domestic solid wastes, in day; Т - time constant of the process of sedimentation of the layers of the placed solid domestic solid wastes, in days. The time of a maximum sedimentation is determined by the formula: t = 3 ·T, where t - time during which the sedimentation process falls into a zone of 5 % from the value of maximum sedimentation of the layers of the placed domestic solid wastes, that is the time of termination of the process.

EFFECT: the invention ensures increased sedimentation of the placed domestic solid wastes at the optimal values of concentration of the introduced bioadditives, decreased required useful area to process the domestic solid wastes, increased accuracy of determination of a time of the sedimentation process termination.

3 ex

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