CN113372488B - Saline-based fracturing fluid thickening agent with reverse polyelectrolyte behavior and preparation method thereof - Google Patents
Saline-based fracturing fluid thickening agent with reverse polyelectrolyte behavior and preparation method thereof Download PDFInfo
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- CN113372488B CN113372488B CN202110737341.7A CN202110737341A CN113372488B CN 113372488 B CN113372488 B CN 113372488B CN 202110737341 A CN202110737341 A CN 202110737341A CN 113372488 B CN113372488 B CN 113372488B
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- C08F—MACROMOLECULAR COMPOUNDS OBTAINED BY REACTIONS ONLY INVOLVING CARBON-TO-CARBON UNSATURATED BONDS
- C08F220/00—Copolymers of compounds having one or more unsaturated aliphatic radicals, each having only one carbon-to-carbon double bond, and only one being terminated by only one carboxyl radical or a salt, anhydride ester, amide, imide or nitrile thereof
- C08F220/02—Monocarboxylic acids having less than ten carbon atoms; Derivatives thereof
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- C09K8/60—Compositions for stimulating production by acting on the underground formation
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- C09K8/86—Compositions based on water or polar solvents containing organic compounds
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Abstract
A saline-based fracturing fluid thickening agent with reverse polyelectrolyte behavior and a preparation method thereof belong to the technical field of oil field oil extraction additives. The amphoteric ionic polymer prepared by taking tribenzylamine, epichlorohydrin, N-dimethyl-1, 3-propane diamine, 2-acrylamide-2-methyl propane sodium sulfonate and acrylamide as main raw materials has obvious reverse polyelectrolyte behavior, can keep higher viscosity in high salinity saline, increases the viscosity of an aqueous solution in a certain mineralization degree range along with the increase of the mineralization degree, and has the advantages of strong sand carrying capacity, easiness in gel breaking and the like. The brine-based fracturing fluid generally configured from the polymer has excellent sand-carrying capacity and fracture-forming capacity. The brine-based fracturing fluid thickening agent with the anti-polyelectrolyte action has excellent brine resistance, is reliable in preparation process, and can be used for preparing the brine-based fracturing fluid thickening agent which is urgently needed at present.
Description
Technical Field
The invention belongs to the technical field of oil field oil extraction additives, and relates to a saline-based fracturing fluid thickening agent with reverse polyelectrolyte behavior and a preparation method thereof, in particular to a saline-based fracturing fluid thickening agent with reverse polyelectrolyte behavior, which is obtained by taking tribenzylamine, epichlorohydrin, N-dimethyl-1, 3-propane diamine, 2-acrylamide-2-methyl propane sodium sulfonate and acrylamide as main raw materials, and a preparation method thereof.
Background
The water-based fracturing fluid which takes natural plant gum and artificially synthesized polymer as a thickening agent is widely applied at home and abroad. The preparation of most fracturing fluids needs to use a large amount of fresh water, and along with the shortage of fresh water resources, great fresh water use pressure is brought to fracturing construction, particularly fracturing operation in arid regions; in addition, because most of low-permeability compact oil reservoirs are water-sensitive oil reservoirs, the oil reservoir is damaged due to the immersion of a large amount of fresh water, and the fracturing effect is seriously influenced. Therefore, a fracturing fluid thickener that can be formulated using formation water with a high degree of mineralization is an urgent need in current fracturing construction.
Disclosure of Invention
The amphoteric polymer with the behavior of the reverse polyelectrolyte solution refers to the electrically neutral amphoteric polyelectrolyte which contains positive and negative charge groups on the macromolecular chain and has equal or similar number, and the viscosity of the polymer in the salt solution cannot be reduced along with the increase of the concentration of the added salt under certain conditions, but is increased along with the increase of the concentration of the added salt, thereby showing very obvious behavior of the reverse polyelectrolyte solution. By utilizing the special solution behavior of the polyelectrolyte, the saline-based fracturing fluid thickening agent which is urgently needed at present can be prepared.
The amphoteric ionic polymer prepared by taking tribenzylamine, epichlorohydrin, N-dimethyl-1, 3-propane diamine, 2-acrylamide-2-methyl propane sodium sulfonate and acrylamide as main raw materials has obvious reverse polyelectrolyte behavior, can keep higher viscosity in high salinity saline, increases the viscosity of an aqueous solution in a certain mineralization degree range along with the increase of the mineralization degree, and has the advantages of strong sand carrying capacity, easiness in gel breaking and the like. The brine-based fracturing fluid generally configured from the polymer has excellent sand-carrying capacity and fracture-forming capacity.
In view of the strong technical demand of fracturing construction for the brine-based fracturing fluid thickener, the invention aims to provide the brine-based fracturing fluid thickener with reverse polyelectrolyte behavior and the preparation method thereof. Firstly, preparing N- (2, 3-epoxypropyl) tribenzylamine by taking tribenzylamine and epoxy chloropropane as raw materials, reacting the N- (2-epoxypropyl) tribenzylamine with N, N-dimethyl-1, 3-propane diamine to prepare N- (3-benzylamino-2-hydroxy-propyl) -N ', N' -dimethyl-1, 3-propane diamine, and reacting the N- (3-benzylamino-2-hydroxy-propyl) -N ', N' -dimethyl-1, 3-propane diamine with epoxy chloropropane and acrylamide to prepare a cationic monomer; then the monomer, 2-acrylamide-2-methyl propyl sodium sulfonate and acrylamide are dissolved in distilled water according to a certain proportion, potassium persulfate is used as an initiator to initiate polymerization, and the zwitterionic copolymer with the obvious reverse polyelectrolyte behavior is prepared. The specific technical scheme is as follows.
The brine-based fracturing fluid thickening agent with the reverse polyelectrolyte behavior is characterized in that the fracturing fluid thickening agent is a polymer gel formed by copolymerizing a cationic monomer, an anionic monomer and acrylamide in an aqueous solution.
Further, the monomers of the fracturing fluid thickening agent are respectively: preparing N- (2, 3-epoxypropyl) tribenzylamine by taking tribenzylamine and epoxy chloropropane as raw materials, reacting the N- (2, 3-epoxypropyl) tribenzylamine with N, N-dimethyl-1, 3-propane diamine to prepare N- (3-benzylamino-2-hydroxy-propyl) -N ', N' -dimethyl-1, 3-propane diamine, and reacting the N- (3-benzylamino-2-hydroxy-propyl) -N ', N' -dimethyl-1, 3-propane diamine with epoxy chloropropane and acrylamide to prepare a cationic monomer; sodium 2-acrylamido-2-methylpropanesulfonate and acrylamide.
Further, the monomer ratio of the fracturing fluid thickening agent is as follows: based on 100 parts of cationic monomer, 100-120 parts of 2-acrylamide-2-methyl sodium propanesulfonate and 270-330 parts of acrylamide.
Parts are based on the amount of material (moles) unless otherwise indicated in the present invention.
Further, the preparation method of the brine-based fracturing fluid thickener with the reverse polyelectrolyte action comprises the following steps:
(1) preparing N- (2, 3-epoxypropyl) tribenzylamine by taking tribenzylamine and epoxy chloropropane as raw materials, reacting the N- (2, 3-epoxypropyl) tribenzylamine with N, N-dimethyl-1, 3-propane diamine to prepare N- (3-benzylamino-2-hydroxy-propyl) -N ', N' -dimethyl-1, 3-propane diamine, and reacting the N- (3-benzylamino-2-hydroxy-propyl) -N ', N' -dimethyl-1, 3-propane diamine with epoxy chloropropane and acrylamide to prepare a cationic monomer;
(2) dissolving a cationic monomer, 2-acrylamide-2-methyl sodium propanesulfonate and acrylamide in distilled water according to a certain proportion, introducing protective gas, and initiating a polymerization reaction under the action of an initiator to prepare the saline-based fracturing fluid thickening agent with the reverse polyelectrolyte behavior.
Further, the specific process for preparing the cationic monomer in the step (1) is as follows: adding 100 parts of tribenzylamine and absolute ethyl alcohol into a reaction vessel, introducing nitrogen, and stirring for dissolving; adding p-toluenesulfonic acid, stirring for dissolving, heating to 30-40 ℃, then slowly dropwise adding 100-120 parts of epoxy chloropropane, reacting at 30-40 ℃ for 10-14 hours after dropwise adding, evaporating ethanol under reduced pressure, cooling, and filtering to obtain light yellow crystal powder; dissolving the mixture and 100-120 parts of N, N-dimethyl-1, 3-propane diamine in distilled water, adding the mixture into a reactor, heating to 75-85 ℃, stirring for reaction for 3-5 h, cooling to 45-55 ℃, slowly dropwise adding 120 parts of epoxy chloropropane under stirring, and reacting at 45-55 ℃ for 2-4 h after dropwise adding to obtain light yellow transparent liquid; and then adding 100-120 parts of acrylamide, stirring for dissolving, heating to 60-70 ℃, reacting for 3-5 hours to generate yellow transparent liquid, and cooling to room temperature for later use.
Further, in the step (2), the ratio of the cationic monomer to the sodium 2-acrylamido-2-methylpropanesulfonate to the acrylamide is as follows: based on 100 parts of cationic monomer, 100-120 parts of 2-acrylamide-2-methyl sodium propanesulfonate and 270-330 parts of acrylamide.
Further, in the step (2), the initiator is potassium persulfate.
Further, the protective gas in the step (2) is nitrogen, the polymerization reaction temperature is 60-70 ℃, and the polymerization reaction time is 4-6 h.
The invention has the following beneficial technical effects: the saline-based fracturing fluid thickening agent with the reverse polyelectrolyte behavior has excellent salt water resistance, is reliable in preparation process, and can be used for preparing the saline-based fracturing fluid thickening agent which is urgently needed at present.
Detailed Description
The technical solution of the present invention is clearly and completely described below. It is to be understood that the described embodiments are merely exemplary of some, and not necessarily all, embodiments of the invention. All other embodiments, which can be obtained by a person skilled in the art without making creative efforts based on the embodiments of the present invention, belong to the protection scope of the present invention.
Example 1
The preparation method of the brine-based fracturing fluid thickener with the anti-polyelectrolyte behavior comprises the following steps:
step (1): adding 0.02mol of tribenzylamine and 30mL of absolute ethyl alcohol into a 100mL three-mouth reaction bottle, introducing nitrogen, stirring for dissolving, adding 0.1 g of p-toluenesulfonic acid, stirring for dissolving, heating to 35 ℃, then slowly dropwise adding 0.02mol of epoxy chloropropane for 2 hours, after dropwise adding, keeping the temperature at 35 ℃ for reaction for 12 hours to obtain yellowish transparent liquid, evaporating the ethanol under reduced pressure, cooling, filtering to obtain pale yellow crystal powder, dissolving the pale yellow crystal powder and 0.02mol of N, N-dimethyl-1, 3-propane diamine into 50mL of distilled water, heating to 80 ℃ in a 250mL reaction bottle, stirring for reaction for 4 hours, cooling to 50 ℃, slowly dropwise adding 0.02mol of epoxy chloropropane under stirring, needing 1 hour, keeping the temperature at 50 ℃ for reaction for 3 hours to obtain pale yellow transparent liquid, then adding 0.02mol of acrylamide, stirring for dissolving, heating to 65 ℃, keeping the temperature for reaction for 4 hours, generating yellow transparent liquid, and cooling at room temperature for later use.
Step (2): 0.02mol of 2-acrylamide-2-methylpropanesulfonic acid sodium salt, 0.06mol of acrylamide and 50mL of distilled water are added into the (1) to be stirred and dissolved, then 0.005g of potassium persulfate is added, nitrogen is introduced for 30 minutes, the temperature is increased to 65 ℃ to initiate polymerization, 5 hours are needed, and the mixture is cooled to room temperature to obtain yellow colloid.
Example 2
The colloid sample obtained in the step (2) of the embodiment 1 is accurately weighed, cut into small pieces, added into clear water, stirred and dissolved, and prepared into a clear water solution with the concentration of 1.0%. Then respectively using clear water and the degree of mineralization being 10000mg/L (wherein Ca)2+The content is 100 mg/L), 30000mg/L (wherein Ca is2+The content is 300 mg/L), 50000mg/L (wherein Ca2+The content is 500 mg/L), 100000mg/L (wherein Ca2+The content is 1000 mg/L), 150000mg/L (wherein Ca2+The content is 1500 mg/L) and 200000mg/L (wherein Ca is2 +Content of 2000 mg/L) simulated formation water was diluted to prepare sample solutions having chemical concentrations of 0.1%, 0.3% and 0.5%, respectively. Measuring the viscosity of each solution at three temperatures of 30 ℃, 60 ℃ and 90 ℃ by using a BROOKFILD DV-III + type rheometer; the results are shown in tables 1 to 7.
TABLE 1 viscosity (mPa.s) of the clear aqueous solutions of the samples
TABLE 2 sample solution viscosity (mPa.s) with degree of mineralization 10000mg/L
TABLE 3 sample solution viscosity (mPa.s) with a mineralization degree of 30000mg/L
TABLE 4 sample solution viscosity (mPa.s) with a degree of mineralization of 50000mg/L
TABLE 5 sample solution viscosity (mPa.s) with a degree of mineralization of 100000mg/L
TABLE 6 sample solution viscosity (mPa.s) with degree of mineralization 150000mg/L
TABLE 7 sample solution viscosity (mPa.s) with a degree of mineralization of 200000mg/L
From tables 1 to 7, it can be seen that the degree of mineralization is from 10000ppm to 150000ppm, and the viscosity of the solution with three concentrations increases with the degree of mineralization, indicating that the salt has the ability to thicken the sample solution.
Example 3
Accurately weighing the colloid sample obtained in the step (2) of the example 1, cutting into small pieces, adding the colloid sample with the mineralization degree of 100000mg/L (wherein, Ca is added2+Content of 1000 mg/L) simulated formation water, stirring and dissolving, respectively preparing sample solutions with the concentration of 0.1 percent, 0.3 percent and 0.5 percent, and shearing various solutions under the conditions of two temperatures of 60 ℃ and 90 ℃, wherein the shearing rate is 7.34s-1The shearing time was 120 minutes, and then the viscosity of each solution after shearing was measured, and the results are shown in Table 8.
TABLE 8 viscosity (mPa.s) of sample solutions after shearing at different concentrations and temperatures
As can be seen from Table 8, the viscosity of the sample solution decreased somewhat after shearing at both temperatures of 60 ℃ and 90 ℃.
Example 4
The colloid sample obtained in the step (2) of example 1 was accurately weighed, cut into small pieces, stirred, and dissolved in simulated formation water having a degree of mineralization of 100000mg/L (wherein the content of Ca2+ was 1000 mg/L) to prepare solutions having a drug concentration of 0.1%, 0.3%, and 0.5%, respectively. Under the three temperature conditions of 30 ℃, 60 ℃ and 90 ℃, the ammonium persulfate microcapsules are used as gel breakers, the addition is 0.05 percent of the solution, gel breaking is carried out on various solutions, and the viscosity of each solution is measured after 30 minutes, and the results are shown in a table 9.
TABLE 9 viscosity (mPa.s) of each solution after 30 minutes of gel breaking at different concentrations and temperatures
Comparing the data in tables 8 and 9, it can be seen that the viscosity of the solution is greatly reduced and is lower than 5 mPa.s after the solution is oxidized and broken by ammonium persulfate, which indicates that the sample solution has better broken capacity.
Although a few embodiments of the present invention have been shown and described, it will be appreciated that the above embodiments are illustrative and not to be construed as limiting the invention, and that those skilled in the art may effect changes, modifications, substitutions and alterations to the above embodiments without departing from the principles and spirit of the invention. The scope of the invention is defined by the claims and their equivalents.
Claims (7)
1. The brine-based fracturing fluid thickening agent with the reverse polyelectrolyte behavior is characterized in that the fracturing fluid thickening agent is a polymer gel formed by copolymerizing a cationic monomer, an anionic monomer and acrylamide in an aqueous solution; the monomers of the fracturing fluid thickening agent are respectively as follows: preparing N- (2, 3-epoxypropyl) tribenzylamine by taking tribenzylamine and epoxy chloropropane as raw materials, reacting the N- (2-epoxypropyl) tribenzylamine with N, N-dimethyl-1, 3-propane diamine to prepare N- (3-tribenzylamine-2-hydroxy-propyl) -N ', N' -dimethyl-1, 3-propane diamine, and reacting the N- (3-tribenzylamine-2-hydroxy-propyl) -N ', N' -dimethyl-1, 3-propane diamine with epoxy chloropropane and acrylamide to prepare a cationic monomer; sodium 2-acrylamido-2-methylpropanesulfonate and acrylamide.
2. The fracturing fluid thickener of claim 1, wherein the monomer ratio of the fracturing fluid thickener is: based on 100 parts of cationic monomer, 100-120 parts of 2-acrylamide-2-methyl sodium propanesulfonate and 270-330 parts of acrylamide.
3. The method for preparing the fracturing fluid thickener according to claim 1 or 2, comprising the steps of:
(1) preparing N- (2, 3-epoxypropyl) tribenzylamine by taking tribenzylamine and epoxy chloropropane as raw materials, reacting the N- (2-epoxypropyl) tribenzylamine with N, N-dimethyl-1, 3-propane diamine to prepare N- (3-tribenzylamine-2-hydroxy-propyl) -N ', N' -dimethyl-1, 3-propane diamine, and reacting the N- (3-tribenzylamine-2-hydroxy-propyl) -N ', N' -dimethyl-1, 3-propane diamine with epoxy chloropropane and acrylamide to prepare a cationic monomer;
(2) dissolving a cationic monomer, 2-acrylamide-2-methyl sodium propanesulfonate and acrylamide in distilled water according to a certain proportion, introducing protective gas, and initiating a polymerization reaction under the action of an initiator to prepare the saline-based fracturing fluid thickening agent with the reverse polyelectrolyte behavior.
4. The method according to claim 3, wherein the step (1) of preparing the cationic monomer comprises the following steps: adding 100 parts of tribenzylamine and absolute ethyl alcohol into a reaction vessel, introducing nitrogen, and stirring for dissolving; adding p-toluenesulfonic acid, stirring for dissolving, heating to 30-40 ℃, then slowly dropwise adding 100-120 parts of epoxy chloropropane, reacting at 30-40 ℃ for 10-14 hours after dropwise adding, evaporating ethanol under reduced pressure, cooling, and filtering to obtain light yellow crystal powder; dissolving the mixture and 100-120 parts of N, N-dimethyl-1, 3-propane diamine in distilled water, adding the mixture into a reactor, heating to 75-85 ℃, stirring for reaction for 3-5 h, cooling to 45-55 ℃, slowly dropwise adding 120 parts of epoxy chloropropane under stirring, and reacting at 45-55 ℃ for 2-4 h after dropwise adding to obtain light yellow transparent liquid; and then adding 100-120 parts of acrylamide, stirring for dissolving, heating to 60-70 ℃, reacting for 3-5 hours to generate yellow transparent liquid, and cooling to room temperature for later use.
5. The method according to claim 3, wherein the ratio of the cationic monomer, sodium 2-acrylamido-2-methylpropanesulfonate and acrylamide in step (2) is: based on 100 parts of cationic monomer, 100-120 parts of 2-acrylamide-2-methyl sodium propanesulfonate and 270-330 parts of acrylamide.
6. The production method according to claim 3, wherein the initiator in the step (2) is potassium persulfate.
7. The preparation method according to claim 3, wherein the protective gas in the step (2) is nitrogen, the polymerization temperature is 60-70 ℃, and the polymerization time is 4-6 h.
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