CN106947450B - Deep profile control and flooding agent with low initial viscosity and preparation method thereof - Google Patents
Deep profile control and flooding agent with low initial viscosity and preparation method thereof Download PDFInfo
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Abstract
The invention discloses a deep profile control and flooding agent with low initial viscosity and a preparation method thereof, wherein the deep profile control and flooding agent contains 0.05-0.2 wt% of hydrophobic association polymer; 0.08-0.16 wt% of formaldehyde and 0.016-0.032 wt% of resorcinol; 0.1-0.16 wt% of oxalic acid; 0.012-0.02 wt% of thiourea; 0.01-0.015 wt% of divalent cobalt salt; the balance of water. The profile control system formed by the profile control agent has low initial viscosity, ensures better injectivity for low-permeability and ultra-low-permeability oil reservoirs, has better temperature resistance, shear resistance and thermal stability, and is beneficial to the long-term effectiveness of colloids in the oil reservoirs. The profile control and flooding system also has stronger plugging capability, profile improvement rate and oil displacement efficiency, and is beneficial to plugging a high-permeability channel, so that the flow direction of an oil reservoir is changed, subsequently injected liquid enters a low-permeability layer, and the effect of improving the recovery ratio is achieved.
Description
Technical Field
The invention relates to a deep profile control agent and a preparation method thereof, in particular to a deep profile control system applied to a high water cut period in a low-permeability oil reservoir, and belongs to the technical field of oil field recovery.
Background
In the tertiary oil recovery technology of the oil field, a low initial viscosity gel profile control system is adopted to carry out deep profile control treatment on the oil reservoir, and the system can block a high permeability channel, adjust the permeability grade difference, improve the water absorption profile, and improve the swept volume and the oil displacement efficiency so as to achieve the purpose of improving the recovery ratio of the oil field.
In the oil reservoir water injection development, due to the heterogeneity of oil reservoir development, the existence of cracks, high permeability zones, large pore canals and the like, the water injection well is prematurely flooded with water corresponding to the oil well, the lateral residual oil of the cracks is enriched, and the lateral oil well water injection is difficult to take effect. The method for improving the crude oil recovery rate still mainly expands the wave and volume of injected water and improves the efficiency of washing oil by injected water as an auxiliary. After years of practical research, people gradually realize that the heterogeneity of an oil reservoir can be adjusted and improved more economically and effectively only by deep profile control and flooding, and the volume sweep coefficient of injected liquid is improved, so that the crude oil recovery rate is improved.
At present, dozens of profile control agents are commonly used at home and abroad, and the profile control materials can be classified into an inorganic type, a polymer type, a foam type and the like. Inorganic materials have the defects of no compressibility, strong mechanical rigidity, difficult injection and small plugging radius, so the inorganic materials are not suitable for being applied to the profile control process of the deep part of the stratum. Foam type materials need to address the problem of air supply. The polymer type material has wider application, but research is mostly focused on medium-high permeability oil reservoirs, and the application of the polymer type material to high-temperature and low-permeability oil reservoirs is less.
Therefore, a novel deep profile control agent needs to be researched for medium-high temperature and low-permeability oil reservoirs.
The following are patents which are currently representative.
The Chinese patent with the application number of '201110298999.9' discloses a low-temperature deep gel profile control and water shutoff agent and a preparation method thereof[1]: the profile control water shutoff agentThe flocculant comprises a polymeric flocculant, a dicyandiamide modified urea-formaldehyde resin delayed cross-linking agent, industrial soda ash, m-aminophenol and water, wherein the weight ratio of each component is as follows: polymeric flocculant: 0.08% -0.2%; dicyandiamide modified urea-formaldehyde resin delayed crosslinking agent: 0.18% -0.25%; industrial soda ash: 0.05% -0.20%; m-aminophenol: 0.01% -0.02%; the balance of water, and the sum of the weight percentages of the components is 100 percent; the reaction temperature is controlled between 50 and 60 ℃. The invention has certain mechanical blocking effect, permanent moving blocking effect, dynamic water blending effect, pressure wave oscillation effect and oil washing and carrying effect, and meets the requirements of high-dose deep profile control and water shutoff and profile control of low-temperature oil reservoirs of oil fields.
The Chinese patent with the application number of 201110417293. X' entitled "a high temperature resistant phenolic resin weak gel profile control water shutoff agent" discloses a high temperature resistant phenolic resin weak gel profile control water shutoff agent, which is a profile control water shutoff agent formed by the reaction of partial hydrolyzed polyacrylamide and a cross-linking agent through the amide group of the partial hydrolyzed polyacrylamide, wherein the profile control water shutoff agent comprises the following raw materials in percentage by weight: 0.25 to 1.2 percent of partially hydrolyzed polyacrylamide, 0.2 to 1 percent of cross-linking agent, 0.01 to 1 percent of additive and the balance of water. The high-temperature-resistant phenolic resin weak gel profile control water shutoff agent provided by the invention has the water shutoff rate of more than 80%, the oil shutoff rate of less than 30%, the high-temperature resistance of more than 90 ℃, the highest mineralization resistance of 85000mg/L (measured by 80000mg/L sodium chloride and 5000mg/L calcium chloride), the gel strength is high, the breakthrough strength is improved by 68% compared with the conventional breakthrough strength, the gelling time is adjustable, the purposes of plugging a high-permeability layer in a stratum and adjusting the water absorption profile of a water injection well at a deep part can be achieved, the deep profile control of an oil layer is realized, and the oil recovery rate is greatly improved.
The Chinese patent with the application number of '201310064509.8' discloses a high-concentration microgel profile control and flooding agent for profile control and flooding of oil fields and a preparation method thereof[3]: aiming at solving the problems of low temperature resistance below 90 ℃, slow effect and poor profile control and flooding effect of the existing gel profile control and flooding agent, the existing preparation method of the gel profile control and flooding agent has low production efficiency and produces micro-scale profile control and flooding agentThe effective content of the gel profile control agent is relatively low. A high-concentration microgel profile control and flooding agent for profile control and flooding of oil fields is prepared from acrylamide monomers, interpenetrating functional monomers, cross-linking agent monomers, emulsifying agents, dispersion media, initiating agents, deionized water and stabilizing agents. Preparation: firstly, preparing a monomer aqueous solution; secondly, preparing an inverse emulsion system; thirdly, carrying out circular flow jet emulsion polymerization reaction. The effective period of the microgel profile control agent is 1-3 months, the effective period is 3-5 years, and the intelligent profile control effect of water plugging and oil plugging can be achieved. The invention is suitable for the field of oil field profile control and flooding.
In the prior art, the research of the profile control agent focuses on the research of the performances such as gel forming time delay, gel forming stability, gel forming strength, temperature resistance, salt tolerance and the like of the gel, is about the research of the performances of the gel, is suitable for medium-high permeability oil reservoirs, and does not need to consider the problem of injectivity. For medium-high temperature and low-permeability complex fault block oil reservoirs, the key is the problem of injectability, so that the prepared profile control system has low viscosity and good injectability during injection, and the research on the aspect is less.
Disclosure of Invention
In order to overcome the defects of gel profile control and flooding agents in the prior art, the invention provides a deep profile control and flooding agent with low initial viscosity, which has low initial viscosity, is beneficial to pumping, has good injectability, better shear resistance and lower viscosity loss rate, and is used for improving the recovery ratio of an oil field.
Therefore, the invention provides the following technical scheme:
a deep profile control agent with low initial viscosity comprises the following components:
hydrophobically associative polymer: the content is 0.05-0.2 wt%;
a crosslinking agent: a mixture of formaldehyde and resorcinol, wherein formaldehyde is 0.08-0.16 wt%, resorcinol is 0.016-0.032 wt%;
acidity regulator: oxalic acid is used as an acidity regulator, and the content of the oxalic acid is 0.1-0.16 wt%;
antioxidant: thiourea is used as an antioxidant, and the content is 0.012-0.02 wt%;
a stabilizer: divalent cobalt salt is used as a stabilizer, and the content is 0.01-0.015 wt%;
the balance of water.
The hydrophobically associative polymer preferably has an average molecular weight of 1200X 104. The formaldehyde to resorcinol weight ratio is preferably 5: 1.
the invention also provides a preparation method of the deep profile control agent with low initial viscosity, which comprises the following steps:
1) preparing 0.5wt% of hydrophobic association polymer mother liquor, and curing for 24 hours at room temperature for later use;
2) respectively preparing 0.5wt% of formaldehyde solution, 0.5wt% of oxalic acid solution, 0.05wt% of resorcinol solution, 0.05wt% of thiourea solution and 0.05wt% of divalent cobalt salt solution;
3) and (2) sequentially adding the hydrophobically associating polymer mother liquor, a formaldehyde solution, an oxalic acid solution, an auxiliary agent and water into the beaker according to a proportion, and uniformly mixing to obtain the profile control agent under the oil reservoir temperature condition.
The most important improvement point of the invention is to find a kind of crosslinking assistant, so that the profile control system formed by applying the profile control agent has low initial viscosity, can reduce injection pressure, ensures better injectability, and is suitable for low-permeability and ultra-low-permeability oil reservoirs. Compared with the prior art, the invention has the beneficial effects that:
1. the low initial viscosity deep profile control agent has low initial viscosity: under the condition of 30 ℃, the initial viscosity range of the profile control and flooding agent is 1.3-2.5 mPa.s; the initial viscosity range of the profile control agent is 1.1-2.3 mPa.s at 90 ℃. In contrast, in the prior art, the initial viscosity of a general profile control system is generally about 10 mPas.
2. The deep profile control agent with low initial viscosity has good temperature resistance, shear resistance and thermal stability, and is beneficial to the long-term effectiveness of colloid in an oil reservoir.
3. The deep profile control agent with low initial viscosity also has strong plugging capability, profile improvement rate and oil displacement efficiency, and is beneficial to plugging a high-permeability channel, so that the flow direction of an oil reservoir is changed, subsequently injected liquid enters a low-permeability layer, and the effect of improving the recovery ratio is achieved.
The deep profile control agent with low initial viscosity is suitable for solving the problems of ineffective circulation of injected water, large pore channels or high permeability channels and the like after low-permeability and ultra-low-permeability oil reservoirs enter a high water-containing period.
Drawings
The invention will be described in further detail with reference to the following drawings and detailed description, which are provided for reference and illustration only and are not intended to limit the invention.
FIG. 1 is a temperature resistance curve for a low initial viscosity deep profile control agent.
FIG. 2 is a graph of shear resistance of a low initial viscosity deep profile control agent.
FIG. 3 is a graph of the stability performance of a low initial viscosity deep profile control agent.
FIG. 4 is a plot of plugging performance for a low initial viscosity deep profile control agent.
FIG. 5 is a graph of enhanced oil recovery capability for a low initial viscosity deep profile control agent.
Detailed Description
Example 1
A deep profile control agent with low initial viscosity comprises the following components:
hydrophobically associative polymer: average molecular weight 1200X 104The content is 0.05 wt%;
a crosslinking agent: a mixture of formaldehyde and resorcinol, wherein formaldehyde is 0.08wt%, resorcinol is 0.016 wt%;
acidity regulator: oxalic acid is used as acidity regulator, and the content is 0.1 wt%;
antioxidant: thiourea as an antioxidant in an amount of 0.012 wt%;
a stabilizer: divalent cobalt salt is used as a stabilizer, and the content is 0.01 wt%;
the balance of water.
The preparation method of the deep profile control agent with low initial viscosity comprises the following steps:
1) preparing 0.5wt% of hydrophobic association polymer mother liquor, and curing for 24 hours at room temperature for later use;
2) respectively preparing 0.5wt% of formaldehyde solution, 0.5wt% of oxalic acid solution, 0.05wt% of resorcinol solution, 0.05wt% of thiourea solution and 0.05wt% of divalent cobalt salt solution;
3) and (3) sequentially adding the hydrophobically associating polymer mother liquor, the formaldehyde solution, the oxalic acid solution, the auxiliary agent and water into the beaker according to the proportion, and uniformly mixing to obtain the profile control agent under the oil reservoir temperature condition.
The following are the experimental results of the low initial viscosity deep profile control agent
1. Temperature resistance
The temperature is one of key factors influencing the gelling of the profile control system, not only influences the gelling time of the profile control system, but also influences the performance of the profile control system, and generally, the higher the temperature is, the faster the gelling is, and the worse the stability is.
Injecting sewage on site to prepare a hydrophobic association polymer into a mother solution, diluting the mother solution to prepare a target solution with the same concentration, adding a cross-linking agent and a cross-linking assistant according to a proportion, respectively putting the mixture into ovens at 69-109 ℃, and measuring the viscosity of a displacement regulating system at different times, wherein the result is shown in figure 1. The experimental result shows that the temperature has great influence on the gelling time, and the gelling time is gradually shortened along with the gradual rise of the temperature; the temperature has little influence on the gel forming strength of the system, and the gel forming strength of the system is slightly lower when the temperature is higher; however, the temperature has a great influence on the stability of the profile control system, and the higher the temperature is, the poorer the stability of the profile control system is.
2. Shear resistance
The profile control system enters the deep part of the stratum through the conveying pipeline, the perforation holes and the stratum near the wellbore zone. The perforation holes and the near wellbore zone stratum have small flow area, large flow and high flow speed. After the perforation holes are sheared at high speed, whether the profile control system can maintain the characteristics of the perforation holes or not is the key of the plugging capability and the displacement effect of the profile control system. High-speed shearing of a first-gear (3500 r/min) and a third-gear (11500 r/min) of a common Wuyi stirrer for 20s simulates the actual shearing action, standing and defoaming are carried out, the mixture is filled into a plastic bottle, the bottle cap is tightly covered, and the mixture is put into a 90 ℃ oven to periodically examine the performance of a profile control and flooding system. The experimental results are shown in table 1 and fig. 2.
TABLE 1 viscosity before and after shear of profile control system
From the results, the gel can be formed after mechanical shearing when the concentrations of the profile control and flooding agent are 800mg/L, 1200mg/L and 1500mg/L, but the gel forming time is relatively prolonged, the higher the shearing strength is, the longer the gel forming time is; the gelling strength after mechanical shearing is reduced to a certain extent, the higher the shearing strength is, the more the gelling strength is reduced, but the reduction range is not large; the stability time of the profile control system subjected to mechanical shearing is almost the same as that of the profile control system not subjected to mechanical shearing, which indicates that the profile control system has good shearing resistance.
3. Thermal stability Properties
The long-term stability of the profile control and flooding system is an important means for evaluating the performance of the profile control and flooding system. The gel forming performance of the profile control system can be influenced to a certain extent under the conditions of oil reservoir temperature and mineralization degree. The unstable manifestation of the profile control system is mainly dehydration. Under the condition of oil reservoir temperature, the profile control and flooding system is easy to thermally degrade, so that the colloid strength is reduced and dehydration occurs, and therefore, one of the keys of the profile control and flooding effect is to ensure the long-term stability of the profile control and flooding system. Preparing a profile control system with different concentrations, periodically measuring the viscosity change of the colloid, observing the dehydration condition, and obtaining an experimental result shown in figure 3. The experiments show that the profile control and flooding system has no dehydration after being aged for 80 days, and the viscosity is reduced by less than 4500 mPa.s, which shows that the profile control and flooding system has better stability at 90 ℃.
4. Plugging performance
The plugging rate can directly reflect the plugging capability of the profile control and flooding agent, and is one of important indexes for evaluating the performance of the profile control and flooding agent. The larger the plugging rate is, the stronger the plugging capability is, and the better the performance is; the smaller the plugging rate, the weaker the plugging ability and the worse the performance.
The calculation formula of the plugging rate is as follows:
（1-1）
in the formula:K 1 ——the permeability of the porous medium before injection of the profile control agent;
K 2 -permeability of the porous medium before and after injection of the profile control agent.
The plugging performance of the profile control agent is researched in a sand-packed pipe artificial rock core device, and the experimental results are shown in table 2 and fig. 4:
TABLE 2 profile control agent plugging Performance parameters
The experimental results show that the plugging rate of the used profile control agent in the simulation experiment of the sand-packed pipe is above 61.85 percent and reaches 97.49 percent at most, the plugging rate is very high, the plugging effect is very good, and the profile control agent establishes higher on-way resistance through physical strength and adsorption with quartz sand after being gelled; the higher the concentration of the plugging agent is, the higher the subsequent water flooding equilibrium pressure is, and the higher the plugging rate is.
5. Breakthrough pressure performance
The breakthrough pressure is characterized by the maximum pressure of the profile control agent in the porous medium with unit length when the water flooding forms breakthrough, the plugging capability of the profile control agent in the porous medium to the water phase fluid is reflected, the strength of the profile control agent can be better reflected, the size of the profile control agent is related to the condition of the porous medium, the ratio of the value to the length of the sand-packed pipe is the breakthrough pressure gradient, and the experimental result is shown in table 3.
Pm=Pmax/L （1-2）
In the formula: pmTo break through the pressure gradient;
Pmaxthe maximum pressure of breakthrough formed by water flooding, MPa;
l is the length of the experimental sand-filling pipe, m.
TABLE 3 breakthrough pressure gradient
The experimental result shows that the maximum breakthrough pressure gradient is 3.41MPa/m, and the plugging formed by the profile control agent can be broken through only by higher pressure, which indicates that the profile control agent can form very strong plugging in the stratum and can meet the plugging requirement of the oil reservoir.
6. Flushing resistance performance
The flushing resistance is also an important characteristic of the profile control and flooding agent, and the flushing resistance refers to effective time that the profile control and flooding agent can still keep the original performance in the stratum after being flushed by subsequent working fluid in the stratum. The flushing resistance of the profile control agent was evaluated by measuring the plugging rate of the core. The retention time of the profile control agent in the rock core is called the effective period of the profile control agent, and the profile control agent with longer effective period still keeps higher plugging rate after being washed by subsequent water flooding. The experimental data and results are shown in table 4.
TABLE 4 results of the scouring resistance test
And after the breakthrough pressure and the plugging rate of the sand filling pipe are measured, continuously scouring by using stratum water, and measuring the permeability and the plugging rate after the simulated stratum water is injected into each certain pore volume multiple. The water injection pressure change trend of the quartz sand in the sand filling pipe after the quartz sand is subjected to the simulated formation water scouring with multiple pore volumes can indicate the water scouring resistance of the profile control agent.
From the experimental results, it can be known that the scouring pressure is not reduced along with the increase of the water injection amount, which indicates that the plugging formed by the used profile control agent can be maintained for a long time, and the plugging has better scouring resistance.
7. Profile improvement capability
The performance of the profile control and flooding system mainly comprises profile improvement and oil displacement effects, an actual oil reservoir is composed of oil layers with different permeabilities, a plugging experiment of a single core only can explain the plugging capability of the profile control and flooding agent in a single stratum, and in order to explain the shunting effect of the profile control and flooding agent on layers with different permeabilities, namely the selective plugging capability in the strata with different permeabilities, the profile control and flooding agent can be simulated by a parallel core profile control and flooding agent experiment.
The plugging condition of the profile control agent on the stratum with different permeability level differences is quantitatively described by the profile improvement rate. Section improvement rate: the quotient of the difference of the water absorption ratios of the high and low permeability layers before and after profile control and flooding and the water absorption ratio of the high and low permeability layers before profile control and flooding.
TABLE 5 selection of plugging Capacity
From the experimental results it can be seen that: after the profile control agent is injected, the water absorption capacity of the high-low permeability core is well improved, and the profile improvement capacity is stronger when the profile control agent concentration is higher. The profile control system has better permeability selectivity, namely, the profile control system preferentially enters a high-permeability large pore passage and rarely enters a low-permeability part.
8. Capacity of increasing recovery ratio
The natural rock core is selected to perform a profile control and flooding experiment on the profile control and flooding agent, and the oil displacement effect of the profile control and flooding agent is shown in table 6 and fig. 5. According to experimental results, the oil displacement agent of 1200mg/L improves the recovery rate by 15.46%, and has a good oil displacement effect. After the modifying and driving agent is gelled, the physical strength and the adsorption on the surface of rock form certain plugging on the dominant channel, so that the liquid flow is diverted, and more residual oil is displaced.
Table 6 oil displacement experimental results of profile control agent in natural rock core
Example 2
A deep profile control agent with low initial viscosity comprises the following components:
hydrophobically associative polymer: average molecular weight 1200X 104The content is 0.2 wt%;
a crosslinking agent: a mixture of formaldehyde and resorcinol, wherein formaldehyde is 0.16wt%, resorcinol is 0.032 wt%;
acidity regulator: oxalic acid is used as an acidity regulator, and the content is 0.16 wt%;
antioxidant: thiourea as an antioxidant in an amount of 0.02 wt%;
a stabilizer: divalent cobalt salt is used as a stabilizer, and the content is 0.015 wt%;
the balance of water.
The preparation method of the deep profile control agent with low initial viscosity comprises the following steps:
1) preparing 0.5wt% of hydrophobic association polymer mother liquor, and curing for 24 hours at room temperature for later use;
2) respectively preparing 0.5wt% of formaldehyde solution, 0.5wt% of oxalic acid solution, 0.05wt% of resorcinol solution, 0.05wt% of thiourea solution and 0.05wt% of divalent cobalt salt solution;
3) and (2) sequentially adding the hydrophobically associating polymer mother liquor, a formaldehyde solution, an oxalic acid solution, an auxiliary agent and water into the beaker according to a proportion, and uniformly mixing to obtain the profile control agent under the oil reservoir temperature condition.
Example 3
A deep profile control agent with low initial viscosity comprises the following components:
hydrophobically associative polymer: the content is 0.1 wt%;
a crosslinking agent: a mixture of formaldehyde and resorcinol, wherein formaldehyde is 0.12wt%, resorcinol is 0.02 wt%;
acidity regulator: oxalic acid is used as an acidity regulator, and the content is 0.12 wt%;
antioxidant: thiourea as an antioxidant in an amount of 0.015 wt%;
a stabilizer: divalent cobalt salt is used as a stabilizer, and the content is 0.01 wt%;
the balance of water.
The deep profile control agent with low initial viscosity can be prepared by the following steps:
1) preparing 0.5wt% of hydrophobic association polymer mother liquor, and curing for 24 hours at room temperature for later use;
2) respectively preparing 0.5wt% of formaldehyde solution, 0.5wt% of oxalic acid solution, 0.05wt% of resorcinol solution, 0.05wt% of thiourea solution and 0.05wt% of divalent cobalt salt solution;
3) and (2) sequentially adding the hydrophobically associating polymer mother liquor, a formaldehyde solution, an oxalic acid solution, an auxiliary agent and water into the beaker according to a proportion, and uniformly mixing to obtain the profile control agent under the oil reservoir temperature condition.
Claims (3)
1. The deep profile control agent with low initial viscosity is characterized by comprising the following components in percentage by weight:
hydrophobically associative polymer: the content is 0.05-0.2 wt%;
a crosslinking agent: a mixture of formaldehyde and resorcinol, wherein formaldehyde is 0.08-0.16 wt%, resorcinol is 0.016-0.032 wt%;
acidity regulator: oxalic acid is used as an acidity regulator, and the content of the oxalic acid is 0.1-0.16 wt%;
antioxidant: thiourea is used as an antioxidant, and the content is 0.012-0.02 wt%;
a stabilizer: divalent cobalt salt is used as a stabilizer, and the content is 0.01-0.015 wt%;
the balance of water;
the low initial viscosity means that: under the condition of 30 ℃, the initial viscosity range of the profile control and flooding agent is 1.3-2.5 mPa.s; the initial viscosity range of the profile control agent is 1.1-2.3 mPa.s at 90 ℃.
2. The deep profile control agent with low initial viscosity of claim 1, wherein: the weight ratio of the formaldehyde to the resorcinol is 5: 1.
3. the method for preparing a deep profile control agent with low initial viscosity according to claim 1, characterized by comprising the following steps:
1) preparing 0.5wt% of hydrophobic association polymer mother liquor, and curing for 24 hours at room temperature for later use;
2) respectively preparing 0.5wt% of formaldehyde solution, 0.5wt% of oxalic acid solution, 0.05wt% of resorcinol solution, 0.05wt% of thiourea solution and 0.05wt% of divalent cobalt salt solution;
3) and (2) sequentially adding the hydrophobic association polymer mother liquor, a formaldehyde solution, an oxalic acid solution, a resorcinol solution, a thiourea solution, a divalent cobalt salt solution and water into the beaker according to a proportion, and uniformly mixing to obtain the profile control and flooding agent under the oil reservoir temperature condition.
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| CN107991305B (en) * | 2017-11-22 | 2020-04-14 | 中国石油大学(北京) | Emulsifier action mechanism research device and method |
| CN109868126B (en) * | 2017-12-01 | 2021-09-28 | 中国石油天然气股份有限公司 | Water plugging agent and preparation method and application thereof |
| CN112442346A (en) * | 2019-09-04 | 2021-03-05 | 中国石油大学(北京) | Salt-resistant and high-temperature-resistant gel plugging agent crosslinked by adopting bisphenol propane and hexamethylenetetramine |
| CN112442347A (en) * | 2019-09-04 | 2021-03-05 | 北京海力森能源科技有限公司 | Salt-resistant and high-temperature-resistant gel plugging agent crosslinked by adopting bisphenol propane and formaldehyde |
| CN111394076A (en) * | 2020-04-24 | 2020-07-10 | 天津鑫源工程技术有限公司 | Preparation method of profile control and flooding agent with efficient plugging effect for low-permeability reservoir |
| CN111423864B (en) * | 2020-05-12 | 2021-05-04 | 燕山大学 | Cementing profile control agent for fractured reservoir and application and use method thereof |
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| WO2011034807A2 (en) * | 2009-09-21 | 2011-03-24 | Baker Hughes Incorporated | Metal-mediated viscosity reduction of fluids gelled with viscoelastic surfactants |
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