CN113372896B - Imbibition oil displacement agent and preparation method thereof - Google Patents
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Abstract
The application discloses a imbibition oil displacement agent and a preparation method thereof. The imbibition oil displacement agent comprises the following components: 20-60 parts by weight of nano active agent material; 10-40 parts by weight of nonionic surfactant; the nano active agent material is obtained by polymerizing a raw material containing a double bond modified lamellar nano material, a hydrophilic monomer and a hydrophobic monomer; the hydrophilic monomer is at least one of anhydride compounds; the hydrophobic monomer is selected from at least one of long-chain alkyl allyl quaternary ammonium salt. The nano active agent material is added into the imbibition oil displacement agent, and the nano active agent material and the nonionic surfactant are combined to play a synergistic effect of the nano active agent material and the nonionic surfactant, so that the high-efficiency imbibition oil displacement agent (system) which is easy to prepare and suitable for the low-permeability oil reservoir is obtained, and the high-efficiency imbibition oil displacement agent has important significance and economic value for improving the development efficiency of the low-permeability oil reservoir.
Description
Technical Field
The application relates to a imbibition oil displacement agent and a preparation method thereof, belonging to the technical field of oil-gas field development.
Background
With the development of oil and gas fields, a plurality of oil fields enter the middle and later stages of development, and a low-permeability oil reservoir becomes an important field for increasing the yield of an old oil field and is a main object for further exploitation in future. However, the low-permeability oil and gas reservoir has the characteristics of poor reservoir physical properties, low stratum energy, low permeability, slow effect of conventional production, high difficulty in reservoir transformation and the like, so that the economic development of the low-permeability oil and gas reservoir is directly restricted. This portion of the reservoir is often accompanied by naturally developing fractures or by formation of a rock matrix-fracture system after reservoir modification, the fractures acting to conduct energy and the rock matrix acting to store oil and energy. Because of the remarkable difference between the fracture permeability and the matrix rock permeability, the development difficulty is higher than that of a conventional oil reservoir, the hydrodynamic force is often poor in connection in the conventional water flooding operation, a large amount of residual oil is enriched after water channeling and flooding, so that the problems of 'injection is not carried out, production is not carried out', and the like are caused, and a great challenge is brought to the development of a low-permeability oil reservoir.
A large number of indoor researches and development practices show that for low-permeability and fractured reservoirs, crude oil can be gradually collected from a pore canal with smaller pore diameter to a large pore canal under the action of capillary force, oil-water displacement is finally realized, and single well yield and recovery ratio are improved, so that the capillary force imbibition effect can be fully exerted, the effective development mode of the reservoirs can be realized, and the development of an efficient imbibition oil displacement agent is significant. Most of the existing imbibition oil displacement agents have the following problems: (1) The preparation process is complex, the operation is not easy, and the reaction conditions are relatively harsh; (2) poor temperature and salt resistance and large adsorption loss to stratum; (3) partial performance is poor, resulting in unsatisfactory imbibition efficiency.
Disclosure of Invention
According to one aspect of the application, a imbibition oil displacement agent is provided, the imbibition oil displacement agent is added with a nano active agent material and combined with a nonionic surfactant to exert the synergistic effect of the nano active agent material and the nonionic surfactant, so that the high-efficiency imbibition oil displacement agent (system) which is easy to prepare and suitable for a hypotonic oil reservoir is obtained, and the high-efficiency imbibition oil displacement agent has important significance and economic value for improving the development efficiency of the hypotonic oil reservoir.
A imbibition oil displacement agent, which comprises the following components:
20-60 parts by weight of nano active agent material;
10-40 parts by weight of nonionic surfactant;
the nano active agent material is obtained by polymerizing a raw material containing a double bond modified lamellar nano material, a hydrophilic monomer and a hydrophobic monomer;
the hydrophilic monomer is at least one of anhydride compounds;
the hydrophobic monomer is selected from at least one of long-chain alkyl allyl quaternary ammonium salt.
Optionally, the imbibition oil displacement agent comprises the following components:
20-60 wt% of nano active agent material;
10-40 wt% of nonionic surfactant;
solvent III balance;
preferably, the imbibition displacement agent comprises the following components:
30-60 wt% of nano active agent material;
30-40 wt% of nonionic surfactant;
solvent III balance.
Optionally, the imbibition oil displacement agent consists of the following components:
20-60 wt% of nano active agent material;
10-40 wt% of nonionic surfactant;
solvent III balance.
Optionally, the nonionic surfactant comprises at least one of alkylphenol ethoxylates, fatty alcohol ethoxylates, coconut oil fatty acid diethanolamides.
Optionally, the alkylphenol ethoxylates comprise at least one of OP-9, OP-10 and TX-10;
the fatty alcohol-polyoxyethylene ether comprises at least one of AEO-7 and AEO-9.
Optionally, the solvent III comprises water.
Optionally, the imbibition oil displacement agent comprises the following components:
20-60 wt% of nano active agent material;
10-20wt% of fatty alcohol polyoxyethylene ether;
10-20wt% of coconut oil fatty acid diethanolamide;
solvent III balance.
Optionally, the imbibition oil displacement agent comprises the following components:
20-60 wt% of nano active agent material;
10 to 20 weight percent of alkylphenol polyoxyethylene ether;
10-20wt% of coconut oil fatty acid diethanolamide;
solvent III balance.
Optionally, the double bond modified lamellar nanomaterial has at least one of the modifying groups shown in formula I;
wherein R is 1 Selected from any one of C1-C4 alkylene, R 2 Selected from any one of C1-C8 alkyl.
Optionally, the lamellar nanomaterial is at least one selected from montmorillonite, bentonite and crystalline flake graphite.
Alternatively, the montmorillonite is selected from sodium-based montmorillonite or calcium-based montmorillonite.
Optionally, the long-chain alkyl allyl quaternary ammonium salt is selected from at least one of long-chain alkyl allyl ammonium halides.
Optionally, the long-chain alkyl allyl ammonium halide is selected from at least one of cetyl dimethyl propylene ammonium chloride, stearyl dimethyl propylene ammonium chloride, tetradecyl dimethyl propylene ammonium chloride and cetyl dimethyl propylene ammonium bromide.
Optionally, the anhydride compound is selected from at least one of maleic anhydride compounds.
Optionally, the maleic anhydride compound is at least one selected from maleic anhydride, methyl maleic anhydride and ethyl maleic anhydride.
Optionally, the nano-active material is obtained by:
and mixing and reacting the double bond modified lamellar nano material, the solution I of the hydrophilic monomer and the hydrophobic monomer and the solution II containing the initiator to obtain the nano active agent material.
Optionally, the mass ratio of the solution I to the solution II is 800-1200: 15-25.
Optionally, the mass ratio of the solution I to the solution II is 900-1100: 18 to 23.
Optionally, the mass ratio of the solution I to the solution II is 950-1050: 20.
optionally, in the solution I, the mass ratio of the double bond modified lamellar nanomaterial, the hydrophilic monomer and the hydrophobic monomer is 0.05-0.5: 100-200: 40 to 100.
Optionally, the mass ratio of the double bond modified lamellar nano material, the hydrophilic monomer and the hydrophobic monomer is 0.05-0.3: 140-180: 50-90.
Optionally, the mass ratio of the double bond modified lamellar nano material, the hydrophilic monomer and the hydrophobic monomer is 0.05-0.2: 150-160: 60 to 80 percent.
Optionally, the initiator is at least one selected from potassium persulfate, sodium persulfate and ammonium persulfate.
Optionally, the solution I contains a solvent I;
the solvent I is water.
Optionally, in the solution I, the mass ratio of the hydrophobic monomer to the solvent is 50-90: 500-900.
Optionally, in the solution I, the mass ratio of the hydrophobic monomer to the solvent is 60-80: 600-800.
Alternatively, the solution I is obtained by: mixing the double bond modified lamellar nano material, the hydrophilic monomer and the hydrophobic monomer, adding the solvent I, and deoxidizing to obtain the solution I.
Optionally, the solution II contains a solvent II;
the solvent II is water.
Optionally, the concentration of the initiator in the solution II is 0.01-1 wt%.
Optionally, in the solution II, the upper concentration limit of the initiator is selected from 0.005%, 0.1%, 0.2%, 0.5%, 0.8% or 1%; the lower limit is selected from 0.001%, 0.005%, 0.1%, 0.2%, 0.5% or 0.8%.
Alternatively, the solution II is obtained by: and dissolving the initiator in the solvent II, and deoxidizing to obtain the solution II.
Optionally, the reaction conditions include: the temperature I is 50-80 ℃.
Optionally, the temperature I is 70-80 ℃.
Optionally, the reaction conditions include: the time is 2-5 h.
Optionally, the time is 2.5-4.5 hours.
Optionally, the preparation method comprises the following steps: and (3) heating the solution I to a temperature II under stirring, dropwise adding the solution II, heating to the temperature I, and reacting.
Optionally, the dropping speed is 2-7 g/min.
Optionally, the dropping speed is 3-5 g/min.
Optionally, the temperature II is 40 to 60 ℃.
Optionally, the stirring speed is 150-350 rpm.
Optionally, the heating rate is 2-8 ℃/min.
According to another aspect of the present application, there is provided a method for preparing a imbibition displacement agent according to any one of the above, the method comprising the steps of:
and mixing the raw materials containing the nano active agent material and the nonionic surfactant to obtain the imbibition oil displacement agent.
Optionally, the preparation method comprises the following steps:
adding the nonionic surfactant into the solvent III, stirring I to obtain a solution A, adding the nano active agent material into the solution A, and stirring II to obtain the imbibition displacement agent;
preferably, the rotational speeds of the stirring I and the stirring II are independently 400-600 rpm.
According to another aspect of the application, there is provided an application of at least one of the imbibition displacement agent of any one of the above and the imbibition displacement agent prepared by the preparation method of any one of the above in the development of hypotonic and/or fractured reservoirs.
The application provides a low-permeability reservoir imbibition oil displacement agent, a preparation method and application thereof, wherein the imbibition oil displacement agent takes a nano active agent material as a main material, combines with a surfactant, plays a synergistic effect of the nano active agent material and the surfactant, forms a high-efficiency imbibition oil displacement agent (system) which is easy to prepare and is suitable for a low-permeability reservoir, and has important significance and economic value for improving development efficiency of the low-permeability reservoir.
The imbibition oil displacement agent comprises the following components:
(1) A nano-active material;
(2) Nonionic surfactant: one or more of alkylphenol ethoxylates, fatty alcohol ethoxylates, coconut oil fatty acid diethanolamides;
(3) And (3) water.
The imbibition oil displacement agent comprises the following components in percentage by mass: 20-60% of nano active agent material, 10-40% of nonionic surfactant and the balance of water.
The preparation method of the imbibition oil displacement agent comprises the following steps:
weighing the raw materials according to the proportion, adding a nonionic surfactant into water, stirring at the stirring speed of 400-600r/min until the mixture is uniform, adding a nano active agent material, and stirring at the same speed until the mixture is uniform, thus obtaining the imbibition oil displacement agent.
In the present application, C1 to C4, C1 to C8, etc. refer to the number of carbon atoms contained in the group.
As used herein, "alkyl" refers to a group formed by the loss of any one of the hydrogen atoms from an alkane compound molecule. The alkane compounds include cycloalkanes, straight-chain alkanes, branched alkanes.
In the application, OP-9, OP-10 and TX-10 are alkylphenol ethoxylates, AEO-7 and AEO-9 are fatty alcohol ethoxylates.
The beneficial effects that this application can produce include:
(1) The imbibition displacement of reservoir oil provided by the application, the nano active agent material is added, the nonionic surfactant is combined, the synergistic effect of the nano active agent material and the nonionic surfactant is exerted, and the high-efficiency imbibition displacement agent (system) which is easy to prepare and suitable for low-permeability reservoir is obtained, and has important significance and economic value for improving development efficiency of low-permeability reservoir.
(2) According to the imbibition displacement of reservoir oil, the added nano active agent material forms a continuous adsorption layer on the surface of oil-wet rock through the action of electrostatic force, hydrogen bond and other chemical bonds, so that the wettability changing capability of a hydrophilic surface enhanced system is formed, and oil drops are adsorbed. Meanwhile, the addition of the nano-active agent increases the interfacial activity, so that a tighter and stable adsorption arrangement is formed on the oil-water interface, a strong hydrophilic nano-film is formed on the wall surface of the rock matrix, the hydrophilicity of the rock is further improved, meanwhile, the tension of the oil-water interface is further reduced, and the crude oil is better emulsified and dispersed. Under the combined actions of changing the wettability and reducing the enhancement of the interfacial tension performance, the imbibition efficiency is greatly improved finally.
(3) The imbibition displacement oil has good temperature resistance.
Detailed Description
The present application is described in detail below with reference to examples, but the present application is not limited to these examples.
Unless otherwise indicated, all starting materials in the examples of the present application were purchased commercially.
Wherein, MT230 used in the application is sodium montmorillonite modified by double bonds, and is produced by inner Mongolian animal health care products, inc., and the model is MT230; the nano active agent material is obtained through the following steps:
(1) 155.6g of maleic anhydride, 68.38g of hexadecyl dimethyl propylene ammonium chloride (AO-4) and 0.1g of M230 are weighed into a three-neck flask, 755g of deionized water is added, stirred and dissolved, nitrogen is introduced for 30min, and oxygen in the solution is removed;
(2) 1g of initiator potassium persulfate is weighed, 20g of deionized water is added, stirring and dissolving are carried out (the concentration of the initiator is 0.5 wt%), nitrogen is introduced for 15min, and oxygen in the solution is removed;
(3) Mechanically stirring the solution obtained in step (1) at 250rpm, starting heating, and setting a heating temperature of 55 ℃; and (3) when the temperature of the solution obtained in step (1) reaches 55 ℃, dropwise adding the potassium persulfate solution obtained in step (2) by using a constant pressure funnel, setting the reaction temperature to 80 ℃, and starting timing after 7 minutes of dropwise adding the initiator, wherein the reaction is finished after the temperature of the reaction solution reaches 80 ℃, so as to obtain the nano active agent material with the molecular weight of 10-30 ten thousand and the particle size of 10-100 nm.
The long 6-block crude oil is provided for the long celebration oil field side.
Example 1 preparation of a low permeability reservoir imbibition displacement agent
The raw materials comprise: 30wt% of nano active agent material, 20wt% of fatty alcohol polyoxyethylene ether (specifically AEO-9), 20wt% of coconut fatty acid diethanolamide and the balance of water.
The preparation method comprises the following steps: adding fatty alcohol polyoxyethylene ether and coconut fatty acid diethanolamide into water, stirring at a stirring speed of 400r/min until the mixture is uniform, adding a nano active agent material, and stirring at the same speed until the mixture is uniform, thereby preparing the imbibition oil displacement agent.
Example 2 preparation of a low permeability reservoir imbibition displacement agent
The raw materials comprise: 60wt% of nano active agent material, 10wt% of fatty alcohol polyoxyethylene ether (specifically AEO-9), 10wt% of coconut fatty acid diethanolamide and the balance of water.
The preparation method comprises the following steps: adding fatty alcohol polyoxyethylene ether and coconut fatty acid diethanolamide into water, stirring at a stirring speed of 400r/min until the mixture is uniform, adding a nano active agent material, and stirring at the same speed until the mixture is uniform, thereby preparing the imbibition oil displacement agent.
Example 3 preparation of a low permeability reservoir imbibition displacement agent
The raw materials comprise: :30wt% of nano active agent material, 20wt% of alkylphenol ethoxylate (specifically OP-10), 10wt% of coconut oil fatty acid diethanolamide and the balance of water.
The preparation method comprises the following steps: adding alkylphenol ethoxylates and coconut fatty acid diethanolamide into water, stirring at a stirring speed of 400r/min until the mixture is uniform, adding nano active agent materials, and stirring at the same speed until the mixture is uniform, thereby preparing the imbibition oil displacement agent.
Comparative example 1 preparation of a low permeability reservoir imbibition displacement agent
The raw materials comprise: 60wt% of nano active agent material, and the balance of water.
The preparation method comprises the following steps: and adding the nano active agent material into water, and stirring at a stirring speed of 500r/min until the nano active agent material is uniform, thus obtaining the imbibition oil displacement agent.
Comparative example 2 preparation of a low permeability reservoir imbibition displacement agent
The raw materials comprise: 30wt% of fatty alcohol polyoxyethylene ether (specifically AEO-9), 30wt% of coconut fatty acid diethanolamide and the balance of water.
The preparation method comprises the following steps: adding fatty alcohol polyoxyethylene ether and coconut fatty acid diethanolamide into water, and stirring at a stirring speed of 400r/min until the mixture is uniform, thus obtaining the imbibition oil displacement agent.
The performance test method comprises the following steps:
the following performance tests were conducted using the prepared long 6-block simulated water (long 6-block simulated water: mineralization 47470mg/L, specific ion composition as shown in Table 1 below) to prepare sample solutions.
Table 1 long 6 block simulated water property list
1. Surface/interfacial tension
Surface tension:
(1) Test sample: diluting the low-permeability reservoir imbibition displacement agents in examples 1-3 and comparative examples 1-2 by 200 times by using long 6-block simulated water to obtain samples to be tested;
(2) The measuring step comprises the following steps: testing with a surface tension meter at 25deg.C, continuously measuring for three times, and taking average value;
interfacial tension:
(1) Test sample: diluting the low-permeability reservoir imbibition displacement agents in examples 1-3 and comparative examples 1-2 by 200 times by using long 6-block simulated water to obtain samples to be tested;
(2) The measuring step comprises the following steps: the average value is obtained by continuously measuring three times by using a TX-500 type rotary drop interfacial tension meter under the condition of 60 ℃ and taking crude oil with a length of 6 blocks as an oil sample.
2. Self-priming height of capillary
(1) Preparation of lipophilic capillaries
(1) Capillary specification: the standard capillary tube with 0.35mm inner diameter is sequentially prepared by using carbon tetrachloride and benzene: acetone: ethanol=7:1.5:1.5 (volume ratio) for 30min, removing surface organic substances;
(2) sequentially carrying out ultrasonic treatment on the capillary surface by using a dilute hydrochloric acid solution (1:10) and a hydrofluoric acid solution (10 percent), and carrying out roughening and activation on the capillary surface for 30min; ultrasonically cleaning with deionized water to remove residual acid until the pH value is more than 6.5 and drying at 105 ℃;
(3) preparing ageing oil according to a proportion, wherein the ageing oil comprises the following components: aviation kerosene: 90# pitch = 2:5:3; immersing the treated capillary tube in aging oil completely, and aging for 2-4 weeks at 60 ℃;
(4) taking out the capillary, soaking the capillary for 2min by using kerosene, and cleaning asphalt deposited on the inner wall and the outer wall of the capillary, so as to not influence observation; drying kerosene outside the tube by nitrogen, and drying in a closed environment at 60 ℃ to obtain the oil wet capillary tube, and preserving for later use.
(2) Test sample preparation
The low permeability reservoir imbibition displacement agents in examples 1 to 3 and comparative examples 1 to 2 were diluted 200 times with 6-block simulated water to obtain samples to be tested. (1) Taking a sample to be measured, adding a carmine indicator (the addition amount is 0.01 wt%) and keeping the temperature of the solution at 25+/-0.2 ℃, pouring the solution to be measured into a cuvette until the top end boundary, and attaching a scale to the rear wall to stand at the rear;
(2) the processed capillaries are vertically placed in a cuvette, the inclined angles of all the capillaries for testing are kept consistent by using a glass slide (the inclined angles are vertically placed), the height difference between the liquid level height in the recording tube and the height of the cuvette is read, and the liquid level height when the capillaries are immersed into the liquid level is recorded respectively for 10 min.
3. Contact angle
Test sample: diluting the low-permeability reservoir imbibition displacement agents in examples 1-3 and comparative examples 1-2 by 200 times by using long 6-block simulated water to obtain samples to be tested; (1) Preparing a hypotonic sandstone core slice with the thickness of about 5mm, polishing the slice with sand paper to be smooth, cleaning the sandstone core slice with alcohol and distilled water, and placing in an oven for one day for drying;
(2) Placing the core slice into long-celebration crude oil, soaking for more than 48 hours at 60 ℃ for aging to make the core slice become an oil-wet surface;
(3) Taking out the sandstone core slice, wiping the surface oil with paper, soaking in a sample to be tested, placing in an oven at 60 ℃ for 24 hours, measuring the three-phase contact angle of the surface of the core slice, air and water by using a gram Lv Shi DSA25 type contact angle measuring instrument, and continuously measuring for three times to obtain the average value.
4. Imbibition efficiency
Test sample: diluting the low-permeability reservoir imbibition displacement agents in examples 1-3 and comparative examples 1-2 by 200 times by using long 6-block simulated water to obtain samples to be tested; (1) core preparation: drilling, cutting and drying an experimental rock core, and measuring gas permeability and porosity; the simulated stratum water is used for saturation in the vacuum pumping of all experimental cores, a constant-pressure constant-speed pump is used for displacement of more than 5PV, and the water phase permeability is measured; then, oil flooding is carried out, the experimental rock core is displaced to a bound water state, the volume of the flooding water is recorded, and the permeability of the bound underwater oil phase is measured;
(2) Placing the experimental rock core into a self-priming instrument filled with a sample to be tested, allowing the rock core to self-prime and discharge oil, and recording the discharge oil quantity changing along with time; when the volume of the discharged oil is not changed for 72 hours, the total volume of the discharged oil is recorded, and self-priming efficiency calculation is carried out.
(3) Self-priming displacement efficiency/% = (self-priming displacement volume/oil displacement water displacement volume) ×100%.
5. Temperature and salt resistance
Test sample: diluting the low-permeability reservoir imbibition displacement agent in examples 1-3 by 200 times by using long 6-block simulated water to obtain a sample to be tested;
temperature resistance: diluting the low-permeability reservoir imbibition displacement agent in examples 1-3 by 200 times by using long 6-block simulated water to obtain a sample to be tested; and sealing a sample to be tested, placing the sealed sample in a baking oven at 150 ℃ for aging for 3 days, taking out the sealed sample, and testing the performance after high-temperature aging according to the measurement methods of the surface/interfacial tension, the self-priming height of the capillary and the contact angle.
Salt tolerance: the low permeability reservoir imbibition displacement agent in examples 1 to 3 was diluted 200 times with 100000mg/L mineralization degree simulated brine to obtain a sample to be measured. The properties at this mineralization level were tested according to the measurement methods of the table/interfacial tension, capillary self-priming height, contact angle, respectively.
Performance test results:
the results of tests 1 to 4 are shown in Table 2.
TABLE 2 results of tests 1-4
As can be seen from the experimental results in Table 2, the system performance after the nano-active agent material and the surfactant are compounded is obviously enhanced compared with that of the single nano-active agent material and the surfactant, wherein the interfacial tension is reduced by one order of magnitude compared with that of the surfactant system, and the imbibition efficiency is improved by more than 15%.
The nano active agent material forms a continuous adsorption layer on the surface of the oil-wet rock through the chemical bond actions of electrostatic force, hydrogen bond and the like, so that a hydrophilic surface is formed to enhance the wettability changing capability of the system, and oil drops are adsorbed. Meanwhile, the addition of the nano active agent material increases the interfacial activity, so that a tighter and stable adsorption arrangement is formed on an oil-water interface, a strong hydrophilic nano film is formed on the wall surface of the rock matrix, the hydrophilicity of the rock is further improved, meanwhile, the tension of the oil-water interface is further reduced, and the crude oil is better emulsified and dispersed.
Under the combined actions of changing the wettability and reducing the enhancement of the interfacial tension performance, the imbibition efficiency is greatly improved finally.
In test 5, the results of the performance tests of examples 1, 2 and 3 after high-temperature aging are similar to those before aging, which shows that the samples have good temperature resistance and no influence on the performance.
The foregoing description is only a few examples of the present application and is not intended to limit the present application in any way, and although the present application is disclosed in the preferred examples, it is not intended to limit the present application, and any person skilled in the art may make some changes or modifications to the disclosed technology without departing from the scope of the technical solution of the present application, and the technical solution is equivalent to the equivalent embodiments.
Claims (16)
1. The imbibition oil displacement agent is characterized by comprising the following components:
20-60wt% of nano active agent material;
10-40 wt% of nonionic surfactant;
solvent III balance
The nano active agent material is obtained by polymerizing a raw material containing a double bond modified lamellar nano material, a hydrophilic monomer and a hydrophobic monomer;
the hydrophilic monomer is at least one of anhydride compounds;
the hydrophobic monomer is at least one of long-chain alkyl allyl quaternary ammonium salt;
the anhydride compound is at least one selected from maleic anhydride compounds;
the long-chain alkyl allyl quaternary ammonium salt is at least one of long-chain alkyl allyl ammonium halides;
the double bond modified lamellar nano material is provided with at least one of modification groups shown in a formula I;
wherein R is 1 Any one selected from C1-C4 alkylene, R 2 Any one of C1-C8 alkyl;
the nano active agent material is obtained through the following steps:
mixing and reacting the double bond modified lamellar nano material, the hydrophilic monomer and the hydrophobic monomer containing solution I and the initiator containing solution II to obtain the nano active agent material;
in the solution I, the mass ratio of the double bond modified lamellar nano material to the hydrophilic monomer to the hydrophobic monomer is 0.05-0.5: 100-200: 40-100.
2. The imbibition displacement agent according to claim 1, characterized in that,
the imbibition oil displacement agent comprises the following components:
30-60wt% of nano active agent material;
30-40 wt% of nonionic surfactant;
solvent III balance.
3. The imbibition displacement agent of claim 1 wherein the nonionic surfactant comprises at least one of alkylphenol ethoxylates, fatty alcohol ethoxylates, coconut oil fatty acid diethanolamides.
4. The imbibition displacement agent according to claim 3, characterized in that,
the alkylphenol ethoxylates comprise at least one of OP-9, OP-10 and TX-10;
the fatty alcohol-polyoxyethylene ether comprises at least one of AEO-7 and AEO-9.
5. The imbibition displacement agent according to claim 1, characterized in that,
the solvent III comprises water.
6. A imbibition displacement agent according to claim 3, characterized in that it comprises the following components:
20-60wt% of nano active agent material;
10-20wt% of fatty alcohol polyoxyethylene ether;
10-20wt% of coconut oil fatty acid diethanolamide;
solvent III balance.
7. The imbibition displacement agent according to claim 3, characterized in that,
the imbibition oil displacement agent comprises the following components:
20-60wt% of nano active agent material;
10-20wt% of alkylphenol ethoxylates;
10-20wt% of coconut oil fatty acid diethanolamide;
solvent III balance.
8. The imbibition displacement agent according to claim 1, characterized in that,
the lamellar nano material is at least one selected from montmorillonite, bentonite and crystalline flake graphite.
9. The imbibition displacement agent according to claim 1, characterized in that,
the initiator is at least one selected from potassium persulfate, sodium persulfate and ammonium persulfate.
10. The imbibition displacement agent according to claim 1, characterized in that,
in the solution II, the concentration of the initiator is 0.01-1wt%.
11. The imbibition displacement agent according to claim 1, characterized in that,
the reaction conditions include: the temperature I is 50-80 ℃.
12. The imbibition displacement agent according to claim 1, characterized in that,
the reaction conditions include: the time is 2-5 h.
13. The method for preparing the imbibition oil displacement agent according to any one of claims 1 to 12, which is characterized by comprising the following steps:
and mixing the raw materials containing the nano active agent material and the nonionic surfactant to obtain the imbibition oil displacement agent.
14. The preparation method according to claim 13, characterized in that the preparation method comprises the steps of:
and adding the nonionic surfactant into the solvent III, stirring I to obtain a solution A, adding the nano active agent material into the solution A, and stirring II to obtain the imbibition oil displacement agent.
15. The method of claim 14, wherein the process comprises,
the rotation speed of the stirring I and the stirring II is independently 400-600 rpm.
16. Use of at least one of the imbibition displacement agent according to any one of claims 1-12 and the imbibition displacement agent prepared by the preparation method according to any one of claims 13-15 in the development of hypotonic and/or fractured reservoirs.
Priority Applications (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202110613591.XA CN113372896B (en) | 2021-06-02 | 2021-06-02 | Imbibition oil displacement agent and preparation method thereof |
| PCT/CN2022/070745 WO2022252620A1 (en) | 2021-06-02 | 2022-01-07 | Imbibition oil displacement agent and preparation method therefor |
Applications Claiming Priority (1)
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| CN113943411A (en) * | 2021-09-24 | 2022-01-18 | 宁波锋成先进能源材料研究院有限公司 | Nano material and preparation method and application thereof |
| CN114133487A (en) * | 2021-11-29 | 2022-03-04 | 宁波锋成先进能源材料研究院有限公司 | Modified cellulose-based polymerization surface agent, emulsification viscosity reducer, preparation method of emulsification viscosity reducer and application of emulsification viscosity reducer in viscosity reduction of thick oil |
| CN114106809A (en) * | 2021-12-10 | 2022-03-01 | 宁波锋成先进能源材料研究院有限公司 | Polymer flooding synergist, preparation method thereof and application of polymer flooding synergist in low-molecular-weight polymer synergistic system |
| CN114410286A (en) * | 2021-12-31 | 2022-04-29 | 宁波锋成先进能源材料研究院有限公司 | Temperature-resistant salt-tolerant nano-imbibition oil displacement agent and preparation method and application thereof |
| CN116120907A (en) * | 2022-12-23 | 2023-05-16 | 宁波锋成纳米科技有限公司 | Nanometer activity synergist for tight oil fracturing and preparation method and application thereof |
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| CN103540307B (en) * | 2012-07-12 | 2016-12-21 | 中国石油化工股份有限公司 | For compositions improving recovery efficiency of high-temperature oil reservoir and preparation method thereof |
| CN104531118B (en) * | 2014-12-25 | 2017-09-12 | 河南正佳能源环保股份有限公司 | A kind of preparation method of intelligent nano oil displacement agent |
| CN111423866A (en) * | 2020-04-30 | 2020-07-17 | 宁波锋成纳米科技有限公司 | Nano oil displacement agent and preparation method and application thereof |
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| CN111944507B (en) * | 2020-09-01 | 2023-04-14 | 宁波锋成先进能源材料研究院有限公司 | Nano active agent system and preparation method and application thereof |
| CN111995722B (en) * | 2020-09-01 | 2021-04-23 | 宁波锋成先进能源材料研究院有限公司 | Organic-inorganic hybrid nano material and preparation method and application thereof |
| CN112239663B (en) * | 2020-10-19 | 2022-07-08 | 中国石油大学(华东) | Oil-in-water emulsion oil displacement agent based on styrene tar and preparation method and application thereof |
| CN112708405B (en) * | 2020-12-30 | 2023-03-24 | 宁波锋成先进能源材料研究院有限公司 | Integrated profile control agent, preparation method and application thereof |
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