CN106590603B - Low-tension foam flooding composition for high-salt formation and preparation method and application thereof - Google Patents

Low-tension foam flooding composition for high-salt formation and preparation method and application thereof Download PDF

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CN106590603B
CN106590603B CN201510681391.2A CN201510681391A CN106590603B CN 106590603 B CN106590603 B CN 106590603B CN 201510681391 A CN201510681391 A CN 201510681391A CN 106590603 B CN106590603 B CN 106590603B
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foaming agent
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nonionic surfactant
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裘鋆
何秀娟
何良好
鲍新宁
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China Petroleum and Chemical Corp
Sinopec Shanghai Research Institute of Petrochemical Technology
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Abstract

The invention relates to a low-tension foam flooding composition for a high-salt stratum, and a preparation method and application thereof. The foaming agent mainly solves the problems that the existing foaming agent has limited capability of reducing oil/water interfacial tension and can not clean residual oil in an oil reservoir, and the low-tension surfactant has poor foaming performance and is difficult to form stable plugging. The low-tension foam flooding composition for the high-salt stratum comprises a nonionic surfactant, a zwitterionic surfactant, water and gas, wherein the nonionic surfactant and the zwitterionic surfactant are dissolved in the water and are mixed with the gas to form foam; wherein the molecular general formula of the nonionic surfactant is R-O- (C)2H4O)m‑(C3H6O)n‑(C2H4O)zThe technical scheme of the-H well solves the problem and can be used for tertiary oil recovery.

Description

Low-tension foam flooding composition for high-salt formation and preparation method and application thereof
Technical Field
The invention relates to a low-tension foam flooding composition for a high-salt stratum, and a preparation method and application thereof.
Background
At present, main oil fields in China enter a high water-cut period, how to improve the recovery ratio of crude oil and furthest develop residual reserves, and a tertiary oil recovery technology plays a very important role in ensuring the stable yield and high yield of the oil fields. In the new technology of tertiary oil recovery, chemical compound flooding is still one of the methods with great development prospect. The oil displacement mechanism of the oil displacement agent is mainly that the polymer or the rubber increases the viscosity of displacement water, reduces the oil-water fluidity ratio, relieves the channeling phenomenon and improves the sweep efficiency; the surfactant and the alkali reduce the oil/water interfacial tension, increase the number of capillary tubes, promote the desorption and effective dispersion of crude oil from rocks, and realize the effective drive of residual oil, thereby improving the recovery ratio. However, most polymers in chemical compound flooding are dry powder and rubber plates, so that the solubility of the polymers is very poor, the temperature resistance and salt resistance of the polymers are poor, and alkali can bring huge damage to the stratum and an oil well.
Foam flooding is receiving increasing attention due to its unique permeability and flooding properties. Foams have better access than polymers or glues and reduce the permeability of high permeability layers. By adding foaming agent and gas for mixing and displacing in the form of foam fluid, the high-permeability band can be selectively blocked, the liquid absorption section can be adjusted, and the sweep coefficient can be increased. The low-tension foam flooding can reduce the oil/water interfacial tension, clean residual oil in an oil reservoir and has the foam plugging capability. However, the core problems of low-tension foam flooding are that the low-tension foam flooding has ultralow interfacial tension, good foam performance, good compatibility with stratum, high temperature resistance and high mineralization resistance.
Currently, low tension foam flooding is also gradually beginning to be studied. For example, patent CN201410190212.0 discloses a high temperature resistant low tension foaming agent, which is composed of alkylphenol polyoxyethylene ether salt, sodium alkylsulfonate salt and sodium chloride. Still another example is 201010521953.4 which provides a temperature and salt tolerant low tension foam formulation comprising an alkanolamide and a bipolar surfactant. But only for reservoirs with a salinity below 100,000 ppm.
Disclosure of Invention
One of the technical problems to be solved by the invention is that the existing foaming agent has limited capability of reducing oil/water interfacial tension and can not clean residual oil in an oil reservoir, and the low-tension surfactant has poor foaming performance and is difficult to form stable plugging. A low tension foam flooding composition for high salt formations is provided which has the advantages of both low interfacial tension and good foam performance.
The second technical problem to be solved by the present invention is to provide a method for preparing a low-tension foam flooding composition for high-salt formations, which solves one of the above technical problems.
The invention also provides an application of the low-tension foam flooding composition for the high-salinity stratum in oil displacement of the oil field, which solves the third technical problem.
In order to solve one of the above technical problems, the technical scheme adopted by the invention is as follows: a low tension foam flooding composition for high salt formations comprising:
(1) a low tension aqueous foam for use in high salt formations;
(2) a gas;
wherein the low-tension foaming agent for the high-salt formation comprises a nonionic surfactant and a zwitterionic surfactant; the mass ratio of the nonionic surfactant to the zwitterionic surfactant is 0.2-10: 1, and the total concentration of the low-tension foaming agent for the high-salt formation is 0.1-2 wt% based on the total mass of the nonionic surfactant and the zwitterionic surfactant; the volume ratio of the gas to the low-tension foaming agent aqueous solution for the high-salt formation is 0.1-10: 1.
In the above technical solution, the nonionic surfactant is selected from at least one of the general molecular formulas shown in formula (I):
R-O-(C2H4O)m-(C3H6O)n-(C2H4O)z-H, formula (I);
wherein R is selected from C1-C20Any one of the aliphatic group and the aryl group of (1); m and n are arbitrary numbers from 0 to 30, and z is an arbitrary number from 1 to 30;
in the above technical scheme, the amphoteric surfactant is selected from betaine surfactants represented by formula (II):
Figure BDA0000825360670000021
wherein R is1Is C1-C26Any of the fatty groups of (a); r2、R3Is independently selected from C1～C5Any one of the alkyl group and the substituted alkyl group of (1); r4Is selected from C1～C5Any one of alkylene or substituted alkylene of (a); y is an anionic group which renders the molecule of formula (II) electrically neutral.
In the above-mentioned embodiments, Y may be any anionic group which renders the general molecular formula (II) electrically neutral, and for example, Y is preferably, but not limited to, -COO—、-SO3 -、-HPO4 —Is more preferably-COO-、-SO3 -At least one of (1).
In the above technical scheme, R1Preferably C1-C26Any one of alkyl and alkenyl of (1), more preferably C12～C18Any one of the alkyl group and the alkenyl group of (1); r2、R3Independently preferably from C1～C5Any one of the alkyl groups of (a), is further independently preferably any one selected from a methyl group, an ethyl group and a propyl group, and is more preferably a methyl group; r4Preferably C1～C3Any one of the alkylene group and the substituted alkylene group of (1).
In the above technical scheme, R is preferably selected from C8-C16Any one of the aliphatic group and the aryl group of (1); more preferably C8-C16Any one of alkyl, alkenyl, alkylbenzene and alkenylbenzene of (1).
In the above technical solution, m is preferably an arbitrary number from 0 to 9; n, z are preferably any number from 3 to 12.
In the technical scheme, the mass ratio of the nonionic surfactant to the zwitterionic surfactant is preferably 0.8-2: 1, and the total concentration of the foaming agent is preferably 0.1-0.3 wt%; the volume ratio of the gas to the low-tension foaming agent aqueous solution for the high-salt formation is preferably 0.5-5: 1; the gas is preferably at least one of air, nitrogen, carbon dioxide, natural gas and flue gas, and is further preferably at least one of air and nitrogen; the total mineralization degree of water in the low-tension foaming agent water solution for the high-salt stratum is 0-200000mg/L, and the total mineralization degree is preferably 100000-200000mg/L, wherein the calcium magnesium ions are 2500-5000 mg/L.
To solve the second technical problem, the invention adopts the following technical scheme: the preparation method of the low-tension foam flooding composition for the high-salt formation in any technical scheme comprises the following steps:
(1) dissolving required amount of nonionic surfactant and zwitterionic surfactant in water according to required mass ratio, and uniformly mixing to obtain the low-tension foaming agent aqueous solution for the high-salt stratum;
(2) and (3) carrying out gas-liquid mixing on the required amount of the low-tension foaming agent aqueous solution for the high-salt formation and the gas to obtain the low-tension foam flooding composition for the high-salt formation.
In order to solve the third technical problem, the technical scheme adopted by the invention is as follows: the composition for low-tension foam flooding of the high-salt stratum in any technical scheme is applied to oil displacement of an oil field.
In the above technical scheme, the application may be foam flooding or foam plugging, and a person skilled in the art may utilize the method according to the related methods in the prior art, and preferably the temperature suitable for the oil reservoir is 50-100 ℃.
The nonionic surfactant of the low-tension foam flooding composition for the high-salt stratum is alkyl alcohol/phenol polyoxyethylene/propylene ether, contains EO/PO fragments, has higher salt resistance, and can reduce the interfacial tension of crude oil and water; the zwitterionic surfactant is long-chain alkyl betaine, is an excellent foaming agent, has good foaming performance and foam stabilizing performance, and forms a compound synergistic effect after being mixed, so that the foaming performance is ensured, and the interfacial tension is reduced to be lower.
The low tension foam flooding composition for high salt formation of the invention can form 10 with the crude oil of the formation-2-10-3The foam has the advantages of ultra-low interface tension of mN/m, strong foaming capability and good foam stability, is applied to indoor tests of a foam composite system, has the foaming volume of more than 250mL and the half-life period of more than 60min (tested by GB/T7462-1994 improved Ross-Miles method for measuring the foaming force of the surfactant), and achieves better technical effect.
Detailed Description
[ example 1 ]
Dissolving a nonionic surfactant and a zwitterionic surfactant in a mass ratio of 0.8:1 in water with a mineralization degree of 117770mg/L and a calcium-magnesium ion content of 2890mg/L, wherein the mass fraction of the nonionic surfactant and the zwitterionic surfactant is 0.3% in terms of the total mass of the nonionic surfactant and the zwitterionic surfactant, uniformly mixing to form a foaming agent aqueous solution, and then realizing gas-liquid mixing with nitrogen in a volume ratio of 5:1 to form the low-tension foam flooding composition for the high-salt stratum.
The above-mentioned aqueous solution of the foaming agent was taken and tested at 50 ℃ by GB/T7462-1994 "determination of foaming power of surfactant-modified Ross-Miles method" to record the foaming volume and the half-life of the foam, and the results are shown in Table 1.
Taking the foaming agent water solution, and controlling the oil-water density difference to be 0.175g/cm at the formation temperature of 73 DEG C3Under the conditions, the oil-water interfacial tension of the oil field and the original oilfield was measured by a spinning drop interfacial tension meter, and the results are shown in table 1.
[ example 2 ]
Dissolving a nonionic surfactant and a zwitterionic surfactant in a mass ratio of 1:1 in water with a mineralization degree of 117770mg/L and a calcium-magnesium ion content of 2890mg/L, wherein the mass fraction of the nonionic surfactant and the zwitterionic surfactant is 0.3% in terms of the total mass of the nonionic surfactant and the zwitterionic surfactant, uniformly mixing to form a foaming agent aqueous solution, and then realizing gas-liquid mixing with nitrogen in a volume ratio of 3:1 to form the low-tension foam flooding composition for the high-salt stratum.
The above-mentioned aqueous solution of the foaming agent was taken and tested at 50 ℃ by GB/T7462-1994 "determination of foaming power of surfactant-modified Ross-Miles method" to record the foaming volume and the half-life of the foam, and the results are shown in Table 1.
Taking the foaming agent water solution, and controlling the oil-water density difference to be 0.175g/cm at the formation temperature of 73 DEG C3Under the conditions, the oil-water interfacial tension of the oil field and the original oilfield was measured by a spinning drop interfacial tension meter, and the results are shown in table 1.
[ example 3 ]
Dissolving a nonionic surfactant and a zwitterionic surfactant in a mass ratio of 2:1 in water with a mineralization degree of 117770mg/L and a calcium-magnesium ion content of 2890mg/L, wherein the mass fraction of the nonionic surfactant and the zwitterionic surfactant is 0.3% in terms of the total mass of the nonionic surfactant and the zwitterionic surfactant, uniformly mixing to form a foaming agent aqueous solution, and then realizing gas-liquid mixing with nitrogen in a volume ratio of 1:1 to form the low-tension foam flooding composition for the high-salt stratum.
The above-mentioned aqueous solution of the foaming agent was taken and tested at 50 ℃ by GB/T7462-1994 "determination of foaming power of surfactant-modified Ross-Miles method" to record the foaming volume and the half-life of the foam, and the results are shown in Table 1.
Taking the foaming agent water solution, and controlling the oil-water density difference to be 0.175g/cm at the formation temperature of 73 DEG C3Under the conditions, the oil-water interfacial tension of the oil field and the original oilfield was measured by a spinning drop interfacial tension meter, and the results are shown in table 1.
[ example 4 ]
Dissolving a nonionic surfactant and a zwitterionic surfactant in a mass ratio of 1.5:1 in water with a mineralization degree of 160000mg/L, wherein the content of calcium and magnesium ions is 4000mg/L, uniformly mixing the water with the nonionic surfactant and the zwitterionic surfactant in a mass fraction of 0.1% to form a foaming agent aqueous solution, and then mixing the foaming agent aqueous solution with air in a volume ratio of 0.5:1 to realize gas-liquid mixing, namely forming the low-tension foam flooding composition for the high-salt stratum.
The above-mentioned aqueous solution of the foaming agent was taken and tested at 50 ℃ by GB/T7462-1994 "determination of foaming power of surfactant-modified Ross-Miles method" to record the foaming volume and the half-life of the foam, and the results are shown in Table 1.
Taking the foaming agent water solution, and controlling the oil-water density difference to be 0.175g/cm at the formation temperature of 73 DEG C3Under the conditions, the oil-water interfacial tension of the oil field and the original oilfield was measured by a spinning drop interfacial tension meter, and the results are shown in table 1.
[ example 5 ]
Dissolving a nonionic surfactant and a zwitterionic surfactant in a mass ratio of 1:1 in water with a mineralization degree of 160000mg/L, wherein the calcium and magnesium ion content is 4000mg/L, and the mass fraction of the nonionic surfactant and the zwitterionic surfactant is 0.2% in terms of the total mass of the nonionic surfactant and the zwitterionic surfactant, uniformly mixing to form a foaming agent aqueous solution, and then realizing gas-liquid mixing with air in a volume ratio of 1:1 to form the low-tension foam flooding composition for the high-salinity stratum.
The above-mentioned aqueous solution of the foaming agent was taken and tested at 50 ℃ by GB/T7462-1994 "determination of foaming power of surfactant-modified Ross-Miles method" to record the foaming volume and the half-life of the foam, and the results are shown in Table 1.
Taking the foaming agent water solution, and controlling the oil-water density difference to be 0.175g/cm at the formation temperature of 73 DEG C3Under the conditions, the oil-water interfacial tension of the oil field and the original oilfield was measured by a spinning drop interfacial tension meter, and the results are shown in table 1.
[ example 6 ]
Dissolving a nonionic surfactant and a zwitterionic surfactant in a mass ratio of 2:1 in water with a mineralization degree of 160000mg/L, wherein the calcium and magnesium ion content is 4000mg/L, and the mass fraction of the nonionic surfactant and the zwitterionic surfactant is 0.3% in terms of the total mass of the nonionic surfactant and the zwitterionic surfactant, uniformly mixing to form a foaming agent aqueous solution, and then realizing gas-liquid mixing with air in a volume ratio of 1:1 to form the low-tension foam flooding composition for the high-salinity stratum.
The above-mentioned aqueous solution of the foaming agent was taken and tested at 50 ℃ by GB/T7462-1994 "determination of foaming power of surfactant-modified Ross-Miles method" to record the foaming volume and the half-life of the foam, and the results are shown in Table 1.
Taking the foaming agent water solution, and controlling the oil-water density difference to be 0.175g/cm at the formation temperature of 73 DEG C3Under the conditions, the oil-water interfacial tension of the oil field and the original oilfield was measured by a spinning drop interfacial tension meter, and the results are shown in table 1.
[ example 7 ]
Dissolving a nonionic surfactant and a zwitterionic surfactant in a mass ratio of 0.8:1 in water with a mineralization degree of 160000mg/L, wherein the content of calcium and magnesium ions is 4000mg/L, uniformly mixing the water with the nonionic surfactant and the zwitterionic surfactant in a mass fraction of 0.1% to form a foaming agent aqueous solution, and then mixing the foaming agent aqueous solution with nitrogen in a volume ratio of 0.5:1 to realize gas-liquid mixing, namely forming the low-tension foam flooding composition for the high-salt stratum.
The above-mentioned aqueous solution of the foaming agent was taken and tested at 50 ℃ by GB/T7462-1994 "determination of foaming power of surfactant-modified Ross-Miles method" to record the foaming volume and the half-life of the foam, and the results are shown in Table 1.
Taking the foaming agent water solution, and controlling the oil-water density difference to be 0.175g/cm at the formation temperature of 73 DEG C3Under the conditions, the oil-water interfacial tension of the oil field and the original oilfield was measured by a spinning drop interfacial tension meter, and the results are shown in table 1.
[ example 8 ]
Dissolving a nonionic surfactant and a zwitterionic surfactant in a mass ratio of 1.5:1 in water with a mineralization degree of 117770mg/L and a calcium-magnesium ion content of 2890mg/L, wherein the mass fraction of the nonionic surfactant and the zwitterionic surfactant is 0.3% in terms of the total mass of the nonionic surfactant and the zwitterionic surfactant, uniformly mixing to form a foaming agent aqueous solution, and then realizing gas-liquid mixing with nitrogen in a volume ratio of 0.5:1 to form the low-tension foam flooding composition for the high-salt stratum.
The above-mentioned aqueous solution of the foaming agent was taken and tested at 50 ℃ by GB/T7462-1994 "determination of foaming power of surfactant-modified Ross-Miles method" to record the foaming volume and the half-life of the foam, and the results are shown in Table 1.
Taking the foaming agent water solution, and controlling the oil-water density difference to be 0.175g/cm at the formation temperature of 73 DEG C3Under the conditions, the oil-water interfacial tension of the oil field and the original oilfield was measured by a spinning drop interfacial tension meter, and the results are shown in table 1.
[ example 9 ]
Dissolving a nonionic surfactant and a zwitterionic surfactant in a mass ratio of 2:1 in water with a mineralization degree of 117770mg/L and a calcium-magnesium ion content of 2890mg/L, wherein the mass fraction of the nonionic surfactant and the zwitterionic surfactant is 0.2% in terms of the total mass of the nonionic surfactant and the zwitterionic surfactant, uniformly mixing to form a foaming agent aqueous solution, and then realizing gas-liquid mixing with nitrogen in a volume ratio of 3:1 to form the low-tension foam flooding composition for the high-salt stratum.
The above-mentioned aqueous solution of the foaming agent was taken and tested at 50 ℃ by GB/T7462-1994 "determination of foaming power of surfactant-modified Ross-Miles method" to record the foaming volume and the half-life of the foam, and the results are shown in Table 1.
Taking the foaming agent waterSolution with oil-water density difference of 0.175g/cm at formation temperature of 73 deg.C3Under the conditions, the oil-water interfacial tension of the oil field and the original oilfield was measured by a spinning drop interfacial tension meter, and the results are shown in table 1.
[ example 10 ]
Dissolving a nonionic surfactant and a zwitterionic surfactant in water with the mineralization degree of 117770mg/L and the calcium and magnesium ion content of 2890mg/L according to the mass ratio of 1.5:1, wherein the mass fraction of the nonionic surfactant and the zwitterionic surfactant is 0.3% in terms of the total mass of the nonionic surfactant and the zwitterionic surfactant, uniformly mixing to form a foaming agent aqueous solution, and then realizing gas-liquid mixing with nitrogen according to the volume ratio of 4:1 to form the low-tension foam flooding composition for the high-salt stratum.
The above-mentioned aqueous solution of the foaming agent was taken and tested at 50 ℃ by GB/T7462-1994 "determination of foaming power of surfactant-modified Ross-Miles method" to record the foaming volume and the half-life of the foam, and the results are shown in Table 1.
Taking the foaming agent water solution, and controlling the oil-water density difference to be 0.175g/cm at the formation temperature of 73 DEG C3Under the conditions, the oil-water interfacial tension of the oil field and the original oilfield was measured by a spinning drop interfacial tension meter, and the results are shown in table 1.
Comparative example 1 interfacial Property test of Low tension foaming agent
C prepared in example 1 was measured using a TX-500C spinning drop interfacial tensiometer12H25O(C2H4O)2(C3H6O)7(C2H4O)12H and the oil-water interfacial tension of the original oilfield. C12H25O(C2H4O)2(C3H6O)7(C2H4O)12H0.1 wt%, formation temperature 73 deg.C, total mineralization 117770mg/L, Ca2+、Mg2+The content is 2890mg/L, and the oil-water density difference is 0.175g/cm3. The results were: the interfacial tension was 0.19 mN/m.
Comparative example 2 interfacial Property test of Low tension foaming agent
Using a TX-500C rotary drop interfacial tensiometerThe interfacial tension between tetradecylbetaine prepared in example 1 and the crude oil field oil and water was measured. 0.2 wt% of tetradecyl betaine, 73 ℃ of formation temperature, 160000mg/L of total mineralization and Ca2+、Mg2+The content is 4000mg/L, and the oil-water density difference is 0.175g/cm3. The results were: the interfacial tension was 1.8 mN/m.
Comparative example 3 foam Performance test of Low tension foaming agent
C prepared in example 112H25O(C2H4O)2(C3H6O)7(C2H4O)12H is prepared into 0.1 wt% aqueous solution, the total mineralization of water is 117770mg/L, Ca2+、Mg2+The content is 2890mg/L, the temperature is 50 ℃, and the test is carried out by GB/T7462-1994 improved Ross-Miles method which is the determination of the foaming power of the surfactant, and the result is that: the foam volume was less than 50 mL.
Comparative example 4 foam Performance test of Low tension foaming agent
The tetradecylbetaine prepared in example 1 was formulated as a 0.3 wt% aqueous solution with a total degree of mineralization of water of 160000mg/L, Ca2+、Mg2+The content is 4000mg/L, the temperature is 50 ℃, and the test is carried out by GB/T7462-1994 improved Ross-Miles method which is the determination of the foaming power of the surfactant, and the result is that: the foam volume was 410mL, and the half-life was 50 min.
Table 1 (wait for)
Examples R m n z R1 R4 Y Degree of water mineralization mg/L Calcium and magnesium concentration mg/L
1 C12H25 2 7 12 C14H29 CH2 -SO3 — 117770 2890
2 C12H23 0 5 10 C12H23 CH2 -SO3 — 117770 2890
3 C8H17 3 11 8 C16H33 CH2CH2 -SO3 — 117770 2890
4 C16H33 5 3 9 C18H35 CH2 -SO3 — 160000 4000
5 C14H22 9 4 6 C14H27 CH2CH2 -SO3 — 160000 4000
6 C10H21 1 12 12 C14H29 CH2 -COO— 160000 4000
7 C15H24 7 6 10 C12H23 CH2 -COO— 160000 4000
8 C10H19 6 10 4 C16H33 CH2CH2 -COO— 117770 2890
9 C14H22 8 4 7 C18H35 CH2 -COO— 117770 2890
10 C8H17 3 9 3 C14H27 CH2CH2 -COO— 117770 2890
TABLE 1 (continuation)
Figure BDA0000825360670000101

Claims (6)

1. A low tension foam flooding composition for high salt formations comprising:
(1) a low tension aqueous foam for use in high salt formations;
(2) a gas;
wherein the low-tension foaming agent for the high-salt formation comprises a nonionic surfactant and a zwitterionic surfactant; the mass ratio of the nonionic surfactant to the zwitterionic surfactant is 0.2-10: 1; the total mass of the nonionic surfactant and the zwitterionic surfactant accounts for the total mass percentage of the low-tension foaming agent aqueous solution, and the concentration of the low-tension foaming agent is 0.1-2%; the volume ratio of the gas to the low-tension foaming agent aqueous solution for the high-salt formation is 0.1-10: 1; the nonionic surfactant is selected from at least one of the molecular general formulas shown in the formula (I):
R-O-(C2H4O)m-(C3H6O)n-(C2H4O)z-H, formula (I);
in the formula (I), R is selected from C8-C16Any one of the aliphatic group and the aryl group of (1); m is any number from 0 to 9 and is greater than 0; n and z are any number from 3 to 12;
the zwitterionic surfactant is selected from betaine surfactants represented by the formula (II):
Figure FDF0000013436950000011
in the formula (II), R is1Is C1-C26Any one of the alkyl group and the alkenyl group of (1); r2、R3Is independently selected from C1～C5Alkyl groups of (a); r4Is C1～C3Any one of the alkylene group and the substituted alkylene group of (1); y is selected from-SO3 —or-COO—(ii) a The total mineralization degree of water in the low-tension foaming agent water solution for the high-salt stratum is 100000-200000mg/L, wherein the calcium magnesium ions are 2500-5000 mg/L.
2. The low tension foam flooding composition for high salt formations of claim 1, characterized in that the R is1Is C12～C18Any one of the alkyl group and the alkenyl group of (1).
3. The low tension foam flooding composition for high salt formation of claim 1, characterized in that the mass ratio of the nonionic surfactant to the zwitterionic surfactant is 0.8-2: 1, and the total concentration of the low tension foam for high salt formation is 0.1-0.5 wt%; the volume ratio of the gas to the low-tension foaming agent aqueous solution for the high-salt formation is 0.5-5: 1.
4. The low tension foam flooding composition for high salt formations of claim 1, characterized in that the gas is selected from any one of air, nitrogen, carbon dioxide, natural gas, flue gas.
5. A method of preparing a low tension foam flooding composition for high salt formations as claimed in any one of claims 1 to 4 comprising the steps of:
(1) dissolving required amount of nonionic surfactant and zwitterionic surfactant in water according to required mass ratio, and uniformly mixing to obtain the low-tension foaming agent aqueous solution for the high-salt stratum;
(2) and (3) carrying out gas-liquid mixing on the required amount of the low-tension foaming agent aqueous solution for the high-salt formation and the gas to obtain the low-tension foam flooding composition for the high-salt formation.
6. The use of any of the low tension foam flooding compositions of claims 1-4 for high salt formations in oil field flooding.
CN201510681391.2A 2015-10-20 2015-10-20 Low-tension foam flooding composition for high-salt formation and preparation method and application thereof Active CN106590603B (en)

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CN103642481A (en) * 2013-12-13 2014-03-19 长江大学 Temperature-resistant and salt-resistant type low-interface tension foam oil-displacing agent and preparation method thereof
CN104109524A (en) * 2013-04-16 2014-10-22 中国石油化工股份有限公司 Reinforced foam flooding composition for high salinity reservoirs, and preparation method thereof
CN104312566A (en) * 2014-09-12 2015-01-28 大连东方创新科技有限公司 Functional polymeric surfactant-reinforced betaine composite flooding system and use thereof

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CN104109524A (en) * 2013-04-16 2014-10-22 中国石油化工股份有限公司 Reinforced foam flooding composition for high salinity reservoirs, and preparation method thereof
CN103642481A (en) * 2013-12-13 2014-03-19 长江大学 Temperature-resistant and salt-resistant type low-interface tension foam oil-displacing agent and preparation method thereof
CN104312566A (en) * 2014-09-12 2015-01-28 大连东方创新科技有限公司 Functional polymeric surfactant-reinforced betaine composite flooding system and use thereof

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