CN112980412A - Modifying and flooding agent suitable for high-temperature high-salinity heavy oil reservoir and preparation method thereof - Google Patents
Modifying and flooding agent suitable for high-temperature high-salinity heavy oil reservoir and preparation method thereof Download PDFInfo
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Abstract
The invention discloses a profile control agent suitable for a high-temperature high-salinity heavy oil reservoir, which is prepared from the following components in percentage by mass: 0.2-0.5% of polymer, 0.01-0.1% of cross-linking agent, 0.2-0.8% of stabilizing agent and the balance of water, wherein the polymer is AM/AMPS or AM/NVP/AMPS. The invention also discloses a preparation method of the profile control agent suitable for the high-temperature high-salinity heavy oil reservoir. The profile control agent suitable for the high-temperature high-salinity heavy oil reservoir provided by the invention has higher viscosity, the crosslinking strength is 800-1200 mPa & s, the viscosity of injected water can be greatly improved, the long-term stability can be kept under the high-temperature high-salinity condition, the water absorption profile can be effectively improved, the problem of water channeling of the injected water is solved, and the water displacement effect under the high-temperature high-salinity oil reservoir condition is improved, so that the heavy oil recovery rate is improved.
Description
Technical Field
The invention relates to the technical field of oil-gas injection well profile control and flooding, in particular to a profile control and flooding agent suitable for a high-temperature high-salinity heavy oil reservoir and a preparation method thereof.
Background
In the process of oil field development, in order to improve the injected water wave and volume and prevent water channeling and other phenomena, the viscosity of the displacement fluid can be improved through the polymer, so that the water-oil fluidity ratio is reduced, and the aim of improving the recovery ratio is fulfilled.
Aiming at high-temperature high-salinity heavy oil reservoirs, temperature-resistant salt-tolerant profile control and flooding agents researched and developed by taking polymers as displacement media have been reported in public. For example, patent CN201310235127.7 discloses a terpolymer for temperature-resistant and salt-resistant flooding and a preparation method thereof, wherein a functional monomer containing both phenyl and sulfonic acid groups is introduced into a macromolecular chain, acrylamide, a sulfonic acid monomer and the functional monomer are prepared into an aqueous solution, then a complexing agent and an aqueous urea solution are added, then an initiator is added, a rubber block is obtained after polymerization, the rubber block is taken out, and a finished terpolymer for temperature-resistant and salt-resistant flooding is obtained by cutting, granulating, crushing and sieving. Although the polymer oil displacement agent has high viscosity, temperature resistance and salt tolerance, and the viscosity retention rate can reach 94% or more after aging for one month at 85 ℃, 3 monomers are required to be added, the steps are complicated, the field construction operation is not facilitated, the viscosity increasing property and the temperature resistance and salt tolerance are limited, and the polymer oil displacement agent is not suitable for high-temperature and high-salt oil reservoirs.
Patent CN201610941753.1 discloses a high temperature resistant deep profile control and displacement agent and a preparation method and application thereof, the high temperature resistant deep profile control and displacement agent comprises a novel high temperature resistant polymer and a high temperature resistant organic composite cross-linking agent, the mass fraction of the novel high temperature resistant polymer is 0.1-0.5%; the mass fraction of the high-temperature resistant organic composite cross-linking agent is 0.1-0.5%. The preparation method comprises the following steps of firstly, adding the novel high-temperature-resistant polymer into uniformly stirred water; step two, stirring uniformly to obtain a profile control agent solution; and step three, putting the profile control agent solution into a thermostat with the temperature of 90-110 ℃ for 2-4 days to fully crosslink the profile control agent solution to obtain semisolid integral gel, thus obtaining the high-temperature-resistant deep profile control agent. The profile control agent has the advantages of simple preparation method, low cost and convenient construction, can achieve the deep profile control effect, but is not suitable for the conditions of high-temperature and high-salinity oil reservoirs with the temperature of 130 ℃ and the mineralization degree of 220000 mg/L.
On the whole, the high-temperature and high-salt polymer oil extraction technology has been researched in many ways, the concept of high-temperature and high-salt is mostly limited to research objects, and some polymer medicament systems with strong practicability are researched and developed in a targeted manner, but the viscosity of a polymer aqueous solution is easily reduced under the conditions of viscosity increasing, temperature resistance and salt tolerance, the water control and oil stabilization effects are lost, and a blank research stage is provided for a polymer which is resistant to salt of 22 milligram/liter and is resistant to 130 ℃.
Therefore, the key to solve the problem of water channeling of the high-temperature and high-salt heavy oil reservoir is to improve the temperature resistance and salt tolerance of the polymer for oil displacement.
Disclosure of Invention
The invention aims to provide a profile control agent suitable for high-temperature high-salinity heavy oil reservoirs, which can effectively increase the viscosity of injected water and prevent stratum blockage caused by too high crosslinking strength aiming at the defects of the prior art. The other purpose is to provide a preparation method for preparing the profile control agent suitable for the high-temperature high-salinity heavy oil reservoir.
In order to achieve the aim, the invention provides a profile control agent suitable for a high-temperature high-salinity heavy oil reservoir, which is prepared from the following components in percentage by mass: 0.2-0.5% of polymer, 0.01-0.1% of cross-linking agent, 0.2-0.8% of stabilizing agent and the balance of water, wherein the polymer is AM/AMPS or AM/NVP/AMPS.
Optionally, according to the modifying and flooding agent suitable for the high-temperature high-salinity heavy oil reservoir, the polymer is AM/AMPS, and the modifying and flooding agent is prepared according to the following steps:
preparing AM and AMPS into an aqueous solution;
adjusting the pH value of the aqueous solution to 6-7, placing the aqueous solution in a water bath at 50 ℃, adding an initiator, and reacting for 10 hours at constant temperature;
after the reaction is finished, the reaction product is purified by absolute ethyl alcohol, dried in a drying oven at 40 ℃ and ground into powder, and the polymer AM/AMPS is obtained.
Optionally, according to the profile control agent for the high-temperature high-salinity heavy oil reservoir, the mass ratio of the AM to the AMPS is 1: 4-1: 1.
Optionally, according to the modifying and flooding agent suitable for the high-temperature high-salinity heavy oil reservoir, the AMPS has the molecular weight of 400-600 ten thousand.
Alternatively, the modifying and flooding agent suitable for the high-temperature high-salinity heavy oil reservoir is a composition of phenols and aldehydes.
Alternatively, the modifying and flooding agent suitable for the high-temperature high-salinity heavy oil reservoir comprises phenol, resorcinol and hydroquinone, and the aldehydes comprise formaldehyde, m-phenylenediamine, p-phenylenediamine and urotropin.
Optionally, according to the profile control agent suitable for the high-temperature high-salinity heavy oil reservoir, the cross-linking agent is hydroquinone and urotropine.
Optionally, according to the profile control agent for the high-temperature high-salinity heavy oil reservoir, the mass ratio of hydroquinone to urotropine is 2: 1-1: 2.
Optionally, according to the modifying and flooding agent suitable for the high-temperature high-salinity heavy oil reservoir, the stabilizing agent is silica sol, silica-alumina sol and aluminum sol.
On the other hand, the invention also provides a preparation method of the profile control agent suitable for the high-temperature high-salinity heavy oil reservoir, which comprises the following steps:
adding the polymer into water, mixing and stirring to obtain a polymer aqueous solution;
adding a cross-linking agent and a stabilizing agent into a polymer aqueous solution, and stirring to obtain a polymer gel solution;
sealing the polymer into a gel, placing the polymer into an oil bath at the temperature of 130 ℃, and aging.
The profile control agent suitable for the high-temperature high-salinity heavy oil reservoir provided by the invention has higher viscosity, the crosslinking strength is 800-1200 mPa & s, the viscosity of injected water can be greatly improved, the long-term stability can be kept under the high-temperature high-salinity condition, the water absorption profile can be effectively improved, the problem of water channeling of the injected water is solved, and the water displacement effect under the high-temperature high-salinity oil reservoir condition is improved, so that the heavy oil recovery rate is improved.
Detailed Description
The invention is further described below with reference to specific embodiments.
On one hand, the invention provides a profile control agent suitable for a high-temperature high-salinity heavy oil reservoir, which is prepared from the following components in percentage by mass: 0.2-0.5% of polymer, 0.01-0.1% of cross-linking agent, 0.2-0.8% of stabilizing agent and the balance of water, wherein the polymer is AM/AMPS or AM/NVP/AMPS. Preferably, the mass fractions of the components are as follows: 0.25-0.3% of polymer, 0.02-0.06% of cross-linking agent, 0.3-0.5% of stabilizing agent and the balance of water. The profile control agent is formed by adding a small amount of cross-linking agent into AM/AMPS (acrylamide/2-acrylamide-2-methylpropanesulfonic acid) or AM/NVP/AMPS (acrylamide/N-vinyl pyrrolidone/2-acrylamide-2-methylpropanesulfonic acid) to cross-link a polymer, so that the profile control agent has higher viscosity, the cross-linking strength is 800-1200 mPa & s, and the cross-linking strength is moderate, so that the viscosity of injected water can be effectively increased, and stratum blockage caused by too high cross-linking strength can be avoided.
Preferably, the polymer is AM/AMPS, which is formed by the free polymerization of AM and AMPS with an initiator, such as ammonium persulfate/sodium bisulfite. For example, AM/AMPS can be prepared as follows:
(1) preparing AM and AMPS into an aqueous solution;
(2) adjusting the pH value of the aqueous solution to 6-7, placing the aqueous solution in a water bath at 50 ℃, adding an initiator, and reacting for 10 hours at constant temperature;
(3) after the reaction is finished, the reaction product is purified by absolute ethyl alcohol, dried in a drying oven at 40 ℃ and ground into powder, and the polymer AM/AMPS is obtained.
In the step (1), the ratio of the reactive monomer (i.e., the total amount of AM and AMPS) is 20 to 30%, and more preferably 20%, based on the total mass of all the reactants. Further, the mass ratio of AM to AMPS is 1: 4-1: 1, preferably 1: 4-3: 7. The molecular weight of the AMPS is preferably 400-600 ten thousand. The amount of the initiator can be adjusted according to the reaction conditions, and preferably, the mole fraction of the initiator is 0.003 to 0.005%, preferably 0.003% based on the total moles of all reactants. The profile control agent of the invention uses AM/AMPS polymer for crosslinking, because the AM content is lower, and the crosslinking effect greatly reduces amide groups, the temperature resistance and salt tolerance of the profile control agent are greatly improved compared with the common polyacrylamide, so that the profile control agent can be suitable for high-temperature and high-salt oil reservoirs.
The preparation method of AM/NVP/AMPS is similar to that of AM/AMPS, and the specific preparation process is not repeated herein.
The cross-linking agent has a great influence on the final gelling properties of the polymer, such as gelling time, viscosity and stability of the polymer after gelling, and the selection of the cross-linking agent is particularly important for this purpose. In the invention, the cross-linking agent is a composition of phenols and aldehydes, wherein the phenols comprise phenol, resorcinol and hydroquinone, and the aldehydes comprise formaldehyde, isophthalaldehyde, terephthaldehyde and urotropine. Further preferably, the cross-linking agent is a composition of hydroquinone and urotropine. Preferably, the mass ratio of hydroquinone to urotropin is 2: 1-1: 2, and further preferably the mass ratio of hydroquinone to urotropin is 2: 1-1: 1.
The stabilizing agent is preferably nano particles comprising silica sol, silica-alumina sol and aluminum sol, and is further preferably silica sol, and the particle size of the silica sol is 12-20 nm. By introducing the nano particles into the profile control agent system, the stability of the profile control agent system under the harsh conditions of high temperature and high salt can be improved.
On the other hand, the invention also provides a preparation method of the profile control agent suitable for the high-temperature high-salinity heavy oil reservoir, which comprises the following steps:
adding the polymer into water, mixing and stirring to obtain a polymer aqueous solution;
adding a cross-linking agent and a stabilizing agent into a polymer aqueous solution, and stirring to obtain a polymer gel solution;
sealing the polymer into a gel, placing the polymer into an oil bath at the temperature of 130 ℃, and aging.
Wherein the aging time is generally 7 to 15 hours. Upon aging, the polymer is crosslinked by the crosslinking agent to form a weakly crosslinked polymer.
In order to specifically describe the invention, the applicant illustrates the profile control agent suitable for high-temperature high-salinity heavy oil reservoirs and the preparation method thereof by the following examples. It should be understood that the following specific examples are illustrative of specific implementations of the invention only and are not to be construed as limiting the scope of the invention.
Example 1
99.43g of simulated water with the mineralization degree of 220000mg/L is weighed into a beaker, 0.25g of AM/AMPS polymer (mass ratio AM: AMPS ═ 3:7) is slowly added into the beaker at the rotation speed of 500r/min while stirring, the mixture is uniformly stirred, 0.02g of cross-linking agent (composition of hydroquinone and urotropine with the mass ratio of 2: 1) and 0.3g of silica sol are added into the beaker, the mixture is uniformly stirred, and the polymer colloid forming liquid is obtained after the mixture is fully mixed. Placing the gel in a sample bottle, sealing, placing in a constant-temperature oil bath at 130 ℃, observing the gelling time to be 12h, wherein the gelling viscosity can reach 930mPa & s, the gelling viscosity of a crosslinking system is higher, and the long-term thermal stability at the high temperature of 130 ℃ is good.
The oil displacement agent provided in the embodiment is considered to improve the recovery efficiency, and the specific experimental process is as follows: drying the artificial sandstone core, saturating with simulated water, saturating the crude oil in the formation at 130 ℃, and aging for 12 h. And then water is driven until the water content reaches 98%, then 0.5PV polymer gel forming liquid is injected into the rock core, the rock core is placed for 12 hours at the formation temperature of 130 ℃, and then water is driven until the water content reaches 98%. Core displacement tests show that the profile control agent can improve the water flooding recovery rate by about 22%.
Example 2
99.33g of simulated water with the mineralization degree of 220000mg/L is weighed into a beaker, 0.35g of AM/AMPS polymer (mass ratio AM: AMPS ═ 3:7) is slowly added into the beaker at the rotation speed of 500r/min while stirring, the mixture is uniformly stirred, 0.02g of cross-linking agent (composition of hydroquinone and urotropine with the mass ratio of 2: 1) and 0.3g of silica sol are added into the beaker, the mixture is uniformly stirred, and the polymer colloid forming liquid is obtained after the mixture is fully mixed. The gel is placed in a sample bottle, sealed and placed in a constant-temperature oil bath at 130 ℃ for observation, the gelling time is 10 hours, the gelling viscosity can reach 1050mPa & s, the gelling viscosity of a crosslinking system is higher, and the long-term thermal stability at the high temperature of 130 ℃ is good.
The oil displacement agent provided in the embodiment is considered to improve the recovery efficiency, and the specific experimental process is as follows: drying the artificial sandstone core, saturating with simulated water, saturating the crude oil in the formation at 130 ℃, and aging for 12 h. And then water is driven until the water content reaches 98%, then 0.5PV polymer gel forming liquid is injected into the rock core, the rock core is placed for 10 hours at the formation temperature of 130 ℃, and then water is driven until the water content reaches 98%. Core displacement tests show that the profile control agent can improve the water flooding recovery by about 25%.
Example 3
99.29g of simulated water with the mineralization degree of 220000mg/L is weighed into a beaker, 0.35g of AM/AMPS polymer (mass ratio AM: AMPS ═ 3:7) is slowly added into the beaker at the rotation speed of 500r/min while stirring, the mixture is uniformly stirred, 0.06g of cross-linking agent (composition of hydroquinone and urotropine with the mass ratio of 2: 1) and 0.3g of silica sol are added into the beaker, the mixture is uniformly stirred, and the polymer colloid forming liquid is obtained after the mixture is fully mixed. The gel is placed in a sample bottle, sealed and placed in a constant-temperature oil bath at 130 ℃ for observation, the gelling time is 7 hours, the gelling viscosity can reach 1190mPa & s, the gelling viscosity of a crosslinking system is higher, and the long-term thermal stability at the high temperature of 130 ℃ is good.
The oil displacement agent provided in the embodiment is considered to improve the recovery efficiency, and the specific experimental process is as follows: drying the artificial sandstone core, saturating with simulated water, saturating the crude oil in the formation at 130 ℃, and aging for 12 h. And then water is driven until the water content reaches 98%, then 0.5PV polymer gel forming liquid is injected into the rock core, the rock core is placed for 7 hours at the formation temperature of 130 ℃, and then water is driven until the water content reaches 98%. Core displacement tests show that the profile control agent can improve the water flooding recovery rate by about 28%.
Example 4
Weighing 99.13g of simulated water with the mineralization degree of 220000mg/L into a beaker, slowly adding 0.35g of AM/AMPS polymer (the mass ratio AM: AMPS is 3:7) at the rotation speed of 500r/min while stirring, uniformly stirring, adding 0.02g of cross-linking agent (a composition of hydroquinone and urotropine in the mass ratio of 2: 1) and 0.5g of silica sol, uniformly stirring, and fully mixing to obtain the polymer gel forming solution. The gel is placed in a sample bottle, sealed and placed in a constant-temperature oil bath at 130 ℃ for observation, the gelling time is 10h, the gelling viscosity can reach 1080mPa & s, the gelling viscosity of a crosslinking system is higher, and the long-term thermal stability at the high temperature of 130 ℃ is good.
The oil displacement agent provided in the embodiment is considered to improve the recovery efficiency, and the specific experimental process is as follows: drying the artificial sandstone core, saturating with simulated water, saturating the crude oil in the formation at 130 ℃, and aging for 12 h. And then water is driven until the water content reaches 98%, then 0.5PV polymer gel forming liquid is injected into the rock core, the rock core is placed for 10 hours at the formation temperature of 130 ℃, and then water is driven until the water content reaches 98%. Core displacement tests show that the profile control agent can improve the water flooding recovery rate by about 26%.
Comparative example 1
99.33g of simulated water with the mineralization degree of 220000mg/L is weighed into a beaker, 0.35g of AM/AMPS polymer (mass ratio AM: AMPS ═ 1:4) is slowly added into the beaker at the rotation speed of 500r/min while stirring, the mixture is uniformly stirred, 0.02g of cross-linking agent (composition of hydroquinone and urotropine with the mass ratio of 2: 1) and 0.3g of silica sol are added into the beaker, the mixture is uniformly stirred, and the polymer colloid forming liquid is obtained after the mixture is fully mixed. The gel is placed in a sample bottle, sealed and placed in a constant-temperature oil bath at 130 ℃ for observation, the gelling time is 9h, the gelling viscosity can reach 1090 mPa.s, the gelling viscosity of a crosslinking system is higher, and the long-term thermal stability at the high temperature of 130 ℃ is good.
The oil displacement agent provided in the embodiment is considered to improve the recovery efficiency, and the specific experimental process is as follows: drying the artificial sandstone core, saturating with simulated water, saturating the crude oil in the formation at 130 ℃, and aging for 12 h. And then water is driven until the water content reaches 98%, then 0.5PV polymer gel forming liquid is injected into the rock core, the rock core is placed for 10 hours at the formation temperature of 130 ℃, and then water is driven until the water content reaches 98%. Core displacement tests show that the profile control agent can improve the water flooding recovery rate by about 27%.
Comparative example 2
99.33g of simulated water with the mineralization degree of 220000mg/L is weighed into a beaker, 0.25g of AM/AMPS polymer (mass ratio AM: AMPS ═ 3:7) is slowly added into the beaker at the rotation speed of 500r/min while stirring, the mixture is uniformly stirred, 0.02g of cross-linking agent (composition of hydroquinone and urotropine with the mass ratio of 1: 1) and 0.3g of silica sol are added into the beaker, the mixture is uniformly stirred, and the polymer colloid forming liquid is obtained after the mixture is fully mixed. The gel is placed in a sample bottle, sealed and placed in a constant-temperature oil bath at 130 ℃ for observation, the gelling time is 14h, the gelling viscosity can reach 860mPa & s, the gelling viscosity of a crosslinking system is higher, and the long-term thermal stability at the high temperature of 130 ℃ is good.
The oil displacement agent provided in the embodiment is considered to improve the recovery efficiency, and the specific experimental process is as follows: drying the artificial sandstone core, saturating with simulated water, saturating the crude oil in the formation at 130 ℃, and aging for 12 h. And then water is driven until the water content reaches 98%, then 0.5PV polymer gel forming liquid is injected into the rock core, the rock core is placed for 14 hours at the formation temperature of 130 ℃, and then water is driven until the water content reaches 98%. Core displacement tests show that the profile control agent can improve the water flooding recovery rate by about 20%.
Comparative example 3
Weighing 99.25g of simulated water with the mineralization degree of 220000mg/L into a beaker, slowly adding 0.35g of AM/AMPS polymer (the mass ratio AM: AMPS is 3:7) at the rotation speed of 500r/min while stirring, uniformly stirring, adding 0.1g of cross-linking agent (a composition of hydroquinone and urotropine in the mass ratio of 2: 1) and 0.3g of silica sol, uniformly stirring, and fully mixing to obtain the polymer gel forming solution. Placing the gel in a sample bottle, sealing, placing in a constant-temperature oil bath at 130 ℃ for observation, wherein the gelling time is 3h, the gelling viscosity can reach 25600mPa & s, and the gelling viscosity of a crosslinking system is too high.
The embodiment shows that the modifying and flooding agent can effectively improve the viscosity of injected water, can be stable for a long time under the conditions of 130 ℃ and the mineralization degree of 220000mg/L, and has excellent temperature resistance and salt tolerance. Therefore, the high-temperature high-salinity heavy oil reservoir profile control agent can effectively improve the water drive effect of a high-temperature high-salinity heavy oil reservoir, is beneficial to improving the recovery ratio of heavy oil, and has long-term stability.
Further, it can be seen from comparison between example 1 and example 2 that the more the amount of the polymer used, the faster the gelling reaction and the greater the gelling viscosity. It can be seen from a comparison of examples 2 and 3 that the more crosslinking agent is used, the faster the gelling reaction and the greater the gelling viscosity. It can be seen from a comparison of example 2 and example 4 that the greater the amount of stabilizer, the greater the gel forming viscosity.
As can be seen by comparing example 2 with comparative example 1, the greater the AMPS content in the total AM/AMPS content, the greater the gelling viscosity. As can be seen by comparing example 2 with comparative example 2, the higher the hydroquinone content in the crosslinking agent, the faster the gelling reaction and the greater the gelling viscosity. It can be seen from the comparison of example 2 and comparative example 3 that too high a crosslinking agent content results in too high gel forming viscosity and too high crosslinking strength to plug the formation.
It should be noted that the above-mentioned embodiments illustrate rather than limit the invention, and that those skilled in the art will be able to design alternative embodiments without departing from the scope of the appended claims. In the claims, any reference signs placed between parentheses shall not be construed as limiting the claim. The word "comprising" does not exclude the presence of elements or steps not listed in a claim. The usage of the words first, second and third, etcetera do not indicate any ordering and these words may be interpreted as names.
Claims (10)
1. The profile control agent suitable for the high-temperature high-salinity heavy oil reservoir is characterized by being prepared from the following components in percentage by mass: 0.2-0.5% of polymer, 0.01-0.1% of cross-linking agent, 0.2-0.8% of stabilizing agent and the balance of water, wherein the polymer is AM/AMPS or AM/NVP/AMPS.
2. The profile control agent suitable for the high-temperature high-salinity heavy oil reservoir according to claim 1, wherein the polymer is AM/AMPS, and is prepared by the following steps:
preparing AM and AMPS into an aqueous solution;
adjusting the pH value of the aqueous solution to 6-7, placing the aqueous solution in a water bath at 50 ℃, adding an initiator, and reacting for 10 hours at constant temperature;
after the reaction is finished, the reaction product is purified by absolute ethyl alcohol, dried in a drying oven at 40 ℃ and ground into powder, and the polymer AM/AMPS is obtained.
3. The profile control agent for the high-temperature high-salinity heavy oil reservoir according to claim 2, wherein the mass ratio of the AM to the AMPS is 1: 4-1: 1.
4. The profile control agent and flooding agent suitable for high-temperature and high-salinity heavy oil reservoirs according to claim 1 or 2, wherein the AMPS has a molecular weight of 400-600 ten thousand.
5. The profile control agent suitable for high-temperature high-salinity heavy oil reservoirs according to claim 1, wherein the cross-linking agent is a composition of phenols and aldehydes.
6. The profile control agent suitable for high-temperature high-salinity heavy oil reservoirs according to claim 5, wherein the phenols comprise phenol, resorcinol and hydroquinone, and the aldehydes comprise formaldehyde, m-phenylenediamine, p-phenylenediamine and urotropin.
7. The profile control agent for high-temperature and high-salinity heavy oil reservoirs according to claim 6, wherein the cross-linking agent is hydroquinone and urotropin.
8. The profile control agent for the high-temperature high-salinity heavy oil reservoir according to claim 7, wherein the mass ratio of hydroquinone to urotropin is 2: 1-1: 2.
9. The profile control agent suitable for the high-temperature high-salinity heavy oil reservoir according to claim 1, wherein the stabilizer is silica sol, silica-alumina sol or aluminum sol.
10. A method for preparing a profile control agent suitable for a high-temperature high-salinity heavy oil reservoir according to any one of claims 1 to 9, which comprises the following steps:
adding the polymer into water, mixing and stirring to obtain a polymer aqueous solution;
adding a cross-linking agent and a stabilizing agent into a polymer aqueous solution, and stirring to obtain a polymer gel solution;
sealing the polymer into a gel, placing the polymer into an oil bath at the temperature of 130 ℃, and aging.
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| CN113897189A (en) * | 2021-11-18 | 2022-01-07 | 中国石油大学(华东) | Jelly glue system suitable for high-temperature high-salinity fracture-cavity oil reservoir profile control and application |
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| CN115216282A (en) * | 2022-07-28 | 2022-10-21 | 中海油能源发展股份有限公司 | Black rubber plugging modifier for high-temperature and high-salinity oil reservoir and preparation method thereof |
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| CN115785929A (en) * | 2022-12-02 | 2023-03-14 | 西南石油大学 | Preparation and application of high-temperature-resistant and hypersalinity-resistant double-crosslinked gel system |
| CN116285921A (en) * | 2023-03-07 | 2023-06-23 | 郭伟 | Chemical plugging composition for offshore oil field and preparation method and application thereof |
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