CN105154030A - Inorganic-organic polymer processing agent for drilling fluid and preparation method thereof - Google Patents

Abstract

The invention provides an inorganic-organic polymer treatment agent for drilling fluid, wherein the treatment agent is formed by polymerization of sulfonic acid monomers, carboxylic acid monomers, nonionic monomers and inorganic materials under the action of an initiator; And the inorganic material includes bentonite. The inorganic-organic polymer treatment agent provided by the invention has strong fluid loss reducing effect in freshwater drilling fluid, brine drilling fluid, saturated brine drilling fluid and composite brine drilling fluid. It also has a strong anti-collapse ability, can effectively control the hydration and dispersion of mud shale, control clay slurry, and has a high permeability recovery value, which has a good oil and gas layer protection effect. Moreover, the production process is simple, the source of raw materials is wide, and the promotion prospect is broad. The invention also provides a preparation method of the inorganic-organic polymer treatment agent for drilling fluid.

Description

Inorganic-organic polymer treatment agent for drilling fluid and preparation method thereof

technical field

The invention relates to an inorganic-organic monomer polymer treatment agent for drilling fluid and a preparation method thereof, belonging to the technical field of synthesis and preparation of water-soluble polymer materials.

Background technique

Since the 1980s, the number of deep wells, ultra-deep wells, and complex wells drilled in various countries in the world has increased, which puts forward higher requirements for drilling fluid technology. Drilling fluid technology must not only meet the requirements of traditional functions, but also meet the requirements of the environment, Requirements for oil layer protection, increasing drilling speed, reducing comprehensive drilling cost, etc. are developing towards the goal of economy, safety and efficiency. The original drilling fluid treatment agents can no longer fully meet the needs of the development of drilling fluid technology, all countries in the world are working hard to develop new drilling fluid treatment agents to meet the needs of the development of drilling fluid technology.

Due to the limitation of new treatment agents, the development of drilling fluid technology in China is slow. Especially in the near future, there is an increasing demand for increasing drilling speed and protecting oil and gas layers. In order to greatly increase drilling speed, protect oil and gas layers to the greatest extent, and finally ensure the production of oil and gas wells, it is necessary to develop new technologies and adaptable drilling technologies. A new type of drilling fluid treatment agent for the development of drilling fluid and completion fluid. Therefore, it is of great significance to develop new products and promote the progress of drilling fluid engineering technology to carry out molecular design and synthesis research of new drilling fluid treatment agents in a timely manner.

However, in recent decades, the research and development of drilling fluid treatment agents have been mainly carried out along the fixed model of organic polymers, and their temperature and salt resistance have become a difficulty in the development of treatment agents. However, if the research and development idea is focused on inorganic compounds, the treatment agent will no longer face the main problem of temperature resistance and salt resistance due to the characteristics of inorganic compounds. In the technical field of research and development of organic polymer treatment agents containing inorganic substances, the inventor first proposed a patent application CN200710180495.0, which discloses a preparation method of an inorganic-organic monomer polymer drilling fluid treatment agent, specifically, Acryloyloxybutyl sulfonic acid, acrylamide, acrylic acid and magnesium silicate gel are used as raw materials, and sodium hydroxide and sodium carbonate are used to adjust the pH value to 9-11, and then an initiator is added for polymerization reaction, and the macromolecular polymerization obtained after the reaction is completed The treatment agent is obtained after drying and pulverizing. The treating agent has achieved obvious effects in field application, but the field still needs to develop an improved and more effective inorganic-organic polymer treating agent for drilling fluid and a preparation method thereof.

Contents of the invention

Therefore, the present invention provides a kind of inorganic-organic polymer treating agent for drilling fluid, wherein, said treating agent is polymerized under the effect of initiator by sulfonic acid monomer, carboxylic acid monomer, nonionic monomer and inorganic material formed; and the inorganic material includes bentonite.

In a specific embodiment, the sulfonic acid monomer is selected from 2-acrylamide-2-methylpropanesulfonic acid, 2-acryloyloxy-2-methylpropanesulfonic acid, acryloyloxybutanesulfonic acid Acid, 2-acrylamide-2-phenylethanesulfonic acid and 2-acrylamide dodecylsulfonic acid, the carboxylic acid monomer is selected from acrylic acid, methacrylic acid, itaconic acid and maleic acid, the The nonionic monomer is selected from acrylamide, N,N-dimethylacrylamide, isobutylacrylamide and acrylonitrile.

The present invention is not particularly limited to the type and amount of the initiator, as long as it can initiate the polymerization of the monomer mixture. For example, the initiator can be an azo initiator, a peroxy initiator and a redox initiator. one or more of the agents. Preferably, the initiator is an oxidation-reduction initiation system comprising an oxidizing agent and a reducing agent, wherein the oxidizing agent is selected from potassium persulfate, ammonium persulfate and sodium persulfate, and the reducing agent is selected from sodium bisulfite, sodium sulfite, sodium thiosulfate, Sodium metabisulfite, ferrous sulfate and ferrous chloride.

In the present invention, the inorganic material may also optionally include silicon magnesium gel, lithium magnesium silicate inorganic gel, aluminum magnesium silicate inorganic gel, aluminum tripolyphosphate, sepiolite and attapulgite, etc. one or more of . In a specific embodiment, the bentonite in the inorganic material accounts for more than 50 wt%, preferably more than 80 wt%, of the total mass of the inorganic material.

The present invention also provides a method for preparing the above-mentioned treatment agent, which includes the following steps: 1) adding inorganic materials into the aqueous solution containing alkali, stirring evenly, grinding with a colloid mill, and grinding to the ground at a temperature not exceeding 35°C. Add sulfonic acid monomer and carboxylic acid monomer to the final mixed solution, continue to stir for 1 minute to 3 hours, then add nonionic monomer to it, and continue to stir for 1 minute to 5 hours to obtain a reaction mixture; 2) Step 1) Put the obtained reaction mixture into a reaction vessel for polymerization, optionally continue stirring for 1 to 30 minutes, adjust the pH value of the solution to 8 to 11 with alkali, add an initiator, and control the initial temperature of the polymerization reaction 35-50°C, react for 2-24 hours to obtain a colloidal product; dry and pulverize the obtained product to obtain the treatment agent.

Compared with the prior art, the invention not only optimizes the added inorganic materials, but also improves the polymerization method for preparing the inorganic-organic polymer treatment agent for drilling fluid. First of all, in the method of the present invention, the inorganic material is added first, and the organic monomer comprising the sulfonic acid monomer, carboxylic acid monomer and nonionic monomer is added after it is ground with a colloid mill, so that the Inorganic materials participate in the reaction better in the polymerization process and increase the introduction of inorganic materials in the treatment agent as much as possible. The introduction amount of inorganic material in the present invention is 5-25wt%, which is obviously greater than that of the corresponding prior art (3.6-8.3wt%); thus the present invention greatly reduces the cost of the polymer on the basis of ensuring the performance of the obtained polymer. Secondly, in the method of the present invention, when adding sulfonic acid monomer and carboxylic acid monomer, the temperature of the system is controlled under the condition of no more than 35°C, so as to prevent the neutralization reaction between the organic acid monomer and the alkali and release heat, which will lead to The self-polymerization of organic monomers ultimately affects the performance of the resulting inorganic-organic polymer treatment agent for drilling fluids. Therefore, compared with the treatment agent in the prior art, the polymer treatment agent obtained by the method of the present invention has the advantages of high performance and low cost.

In a specific example of the above-mentioned preparation method, the mass percentage of the inorganic material in the raw materials used before the polymerization to the total mass of the sulfonic acid monomer, carboxylic acid monomer, non-ionic monomer and inorganic material is 5-25% %, preferably 10 to 20%. As mentioned above, when more inorganic materials are used, the cost of the polymer can be greatly reduced on the basis of improving the performance of the obtained polymer.

In the above preparation method, preferably, the ratio of the amount of substances among the sulfonic acid monomer, the carboxylic acid monomer and the nonionic monomer in step 1) is 10-40:10-25:80-35. In addition, the preferred amount of water in the reaction mixture in step 1) is to control the total mass of the reaction raw materials to be 40-60% of the mass of the reaction mixture.

In a specific example of the above preparation method, the amount of the initiator is 0.2-0.75 wt% of the total mass of the sulfonic acid monomer, carboxylic acid monomer and nonionic monomer, and the amount of the oxidizing agent and the reducing agent The mass ratio is 1:1-2.5. In another example, the ratio of the amount of the base used in step 1) to the sum of the amounts of the carboxylic acid monomer and the sulfonic acid monomer is 1:0.9-1.1, preferably 1:1.

The inorganic-organic polymer treatment agent provided by the invention has strong fluid loss reducing effect in freshwater drilling fluid, brine drilling fluid, saturated brine drilling fluid and composite brine drilling fluid. It also has a strong anti-collapse ability, can effectively control the hydration and dispersion of mud shale, control clay slurry, and has a high permeability recovery value, which has a good oil and gas layer protection effect. Moreover, the production process is simple, the source of raw materials is wide, and the promotion prospect is broad. Generally speaking, the additive provided by the invention can meet the needs of safe drilling construction under high temperature and/or high salt conditions, and can control the rheology, suspension stability and fluid loss of water-based drilling fluid under high temperature and high pressure conditions.

Detailed ways

The present invention will be described in detail below in combination with specific embodiments. It should be understood that the specific embodiments described here are only used to illustrate and explain the present invention, and are not intended to limit the present invention.

The bentonite used in the present invention is the product of Weifang Pengxiang Bentonite Co., Ltd., the aluminum tripolyphosphate used is the product of Shijiazhuang Kunyuan Chemical Co., Ltd., and the attapulgite is produced from Lingshou County Baidatong Mineral Products Processing Plant.

Examples 1 to 5 are for preparing the inorganic-organic polymer treatment agent obtained in the present invention.

Example 1

1) Add 22.8 kg of potassium hydroxide and 130 kg of water into the neutralization kettle, add 21 kg of bentonite after complete dissolution, and grind with a colloid mill after stirring evenly. Add the ground mixed liquid to the reaction kettle, and slowly add 48 kg of 2-acrylamide dodecylsulfonic acid and 18 kg of acrylic acid under the condition that the temperature does not exceed 35°C, and continue stirring for 10 to 15 minutes after the addition is complete. Add 55 kg of N,N-dimethylacrylamide, and continue to stir for 25 to 30 minutes after the addition to obtain a reaction mixture;

2) Add the reaction mixture obtained in step 1) into the polymerization tank, stir for 5-10 minutes, and adjust the pH value of the system to 10.5 with a sodium hydroxide solution with a mass fraction of 10%-40%. Add 0.6 kg of sodium persulfate and 1.2 kg of ferrous sulfate (an aqueous solution prepared with an appropriate amount of water), stir for about 9 minutes and then stand still, control the initial temperature of the polymerization reaction to be 45-50 ° C, and react for 8 hours to obtain a colloidal product; The obtained product was dried at 130-140° C. and pulverized to obtain the sample of Example 1.

Example 2

1) Add 14 kg of sodium hydroxide and 160 kg of water into the neutralization kettle, add 18 kg of bentonite after complete dissolution, and grind with a colloid mill after stirring evenly. Add the ground mixed liquid to the reaction kettle, and slowly add 20.8 kg of acryloyloxybutanesulfonic acid and 29 kg of maleic acid under the condition that the temperature does not exceed 35 ° C, and continue stirring for 15 to 25 minutes after the addition is complete. Add 26.5 kg of acrylonitrile, and continue to stir for 25 to 30 minutes after the addition, to obtain a reaction mixture;

2) Add the reaction mixture obtained in step 1) into the polymerization tank, stir for 5-10 minutes, and adjust the pH value of the system to 11.0 with a sodium hydroxide solution with a mass fraction of 10%-40%. Add 0.35 kg of sodium persulfate and 0.7 kg of ferrous chloride (an aqueous solution prepared with an appropriate amount of water), stir for about 5 to 15 minutes and then stand still, control the initial temperature of the polymerization reaction at 45 to 50 ° C, and react for 7 hours to obtain gelatin Shaped product; the obtained product was dried at 120-130° C. and pulverized to obtain the sample of Example 2.

Example 3

1) Add 35 kg of potassium bicarbonate and 150 kg of water into the neutralization kettle, add 14 kg of bentonite and 3.5 kg of aluminum tripolyphosphate after being completely dissolved, and grind with a colloid mill after stirring evenly. Add the ground mixture into the reaction kettle, slowly add 20.8 kg of 2-acryloyloxy-2-methylpropanesulfonic acid and 32.5 kg of itaconic acid under the condition that the temperature does not exceed 35°C, and continue stirring after the addition is complete 15-20 minutes. Add 49.5 kg of N,N-dimethylacrylamide, and continue stirring for 15 to 20 minutes after the addition, to obtain a reaction mixture;

2) Add the reaction mixture obtained in step 1) into the polymerization tank, stir for 5-10 minutes, and adjust the pH value of the system to 8.5 with a sodium hydroxide solution with a mass fraction of 10%-40%. Add 0.35 kg of ammonium persulfate and 0.7 kg of sodium metabisulfite (an aqueous solution prepared with an appropriate amount of water), stir for about 5 to 15 minutes and then stand still, control the initial temperature of the polymerization reaction at 40 to 45 ° C, and react for 15 hours to obtain a gelatinous product ;Dry the resulting product at 130-140°C and pulverize it to obtain the sample of Example 3.

Example 4

1) Add 13 kg of sodium hydroxide and 120 kg of water into the neutralization kettle, add 24 kg of bentonite after complete dissolution, and grind with a colloid mill after stirring evenly. Add the ground mixture into the reaction kettle, slowly add 30 kg of 2-acrylamide-2-phenylethanesulfonic acid and 15 kg of acrylic acid under the condition that the temperature does not exceed 35 °C, and continue to stir for 20 to 25 minutes after the addition is complete . Add 19 kg of isobutylacrylamide and 35.5 kg of acrylamide, and continue stirring for 25 to 30 minutes after the addition to obtain a reaction mixture;

2) Add the reaction mixture obtained in step 1) into the polymerization tank, stir for 5-10 minutes, and adjust the pH value of the system to 9.0 with a sodium hydroxide solution with a mass fraction of 10%-40%. Add 0.25 kg of sodium persulfate and 0.5 kg of sodium sulfite (an aqueous solution prepared with an appropriate amount of water), stir for about 8 minutes and then stand still, control the initial temperature of the polymerization reaction to be 45-50 ° C, and react for 16 hours to obtain a colloidal product; The product was dried at 130-135° C. and pulverized to obtain the sample of Example 4.

Example 5

1) Add 67.5 kg of potassium carbonate and 200 kg of water into the neutralization kettle, add 14 kg of bentonite and 3 kg of attapulgite after being completely dissolved, and grind with a colloid mill after stirring evenly. Add the ground mixed solution into the reaction kettle, and slowly add 70 kg of 2-acrylamide-2-methylpropanesulfonic acid and 13 kg of methacrylic acid under the condition that the temperature does not exceed 35 °C, and continue to stir for 15 ~ 20 minutes. Add 40 kg of acrylamide, and continue stirring for 25 to 30 minutes after the addition, to obtain a reaction mixture;

2) Add the reaction mixture obtained in step 1) into the polymerization tank, stir for 5-10 minutes, and adjust the pH value of the system to 9.0 with a sodium hydroxide solution with a mass fraction of 10%-40%. Add 0.8 kg of potassium persulfate and 1.6 kg of ferrous chloride (an aqueous solution prepared with an appropriate amount of water), stir for about 8 minutes and then stand still, control the initial temperature of the polymerization reaction at 40-45 ° C, and react for 5 hours to obtain a colloidal product ;Dry the resulting product at 125-130°C and pulverize it to obtain the sample of Example 5.

Comparative example 1

This example is an organic polymer treatment agent prepared for comparison.

1) Add 22.8 kg of potassium hydroxide and 130 kg of water into the neutralization tank, and slowly add 48 kg of 2-acrylamide dodecylsulfonic acid and 18 kg of acrylic acid under the condition that the temperature does not exceed 35°C after complete dissolution. Continue to stir for 10 to 15 minutes after the addition is complete. Add 55 kg of N,N-dimethylacrylamide, and continue to stir for 25 to 30 minutes after the addition to obtain a reaction mixture;

2) Add the reaction mixture obtained in step 1) into the polymerization tank, stir for 5-10 minutes, and adjust the pH value of the system to 10.5 with a sodium hydroxide solution with a mass fraction of 10%-40%. Add 0.6 kg of sodium persulfate and 1.2 kg of ferrous sulfate (an aqueous solution prepared with an appropriate amount of water), stir for about 9 minutes and then stand still, control the initial temperature of the polymerization reaction to be 45 to 50 ° C, and react for 8 hours to obtain a colloidal product. The obtained product was dried at 130-140° C. and pulverized to become the sample of Comparative Example 1.

Comparative example 2

This example is to prepare the polymer treatment agent for comparison.

The colloidal product prepared in step 2) of Comparative Example 1 and 21 kg of bentonite were directly mixed and stirred evenly, dried at 120-130° C., and pulverized to become the sample of Comparative Example 2.

The present invention provides the application of the inorganic-organic monomer polymer as a drilling fluid treatment agent in the following specific embodiments. In order to illustrate the effect of the present invention, the sample synthesized in Example 1 (represented by code SM-4 for ease of description) is used as a representative to introduce the performance of the application. The treatment agent is SM-4.

In the performance evaluation of the present invention, calcium bentonite complies with SY/T5060-1993 standard; sodium bentonite complies with SY/T5060-1993 standard; salt-resistant soil complies with SY/T5603-1993 standard; anhydrous calcium chloride, chemically pure ; Sodium chloride, analytically pure; Magnesium chloride, analytically pure; Anhydrous sodium carbonate, analytically pure. High-speed mixer, GJ-1 type; medium pressure water loss meter, ZNS type; six-speed rotary viscometer, ZNN-D6 type; high temperature rolling oven 50-300 °C.

Wherein, base slurry is prepared as follows:

1) Fresh water base slurry: Add 3g of soda ash and 40g of calcium or sodium bentonite to 1000mL tap water, stir for 8 hours, and place at room temperature for 48 hours to obtain fresh water base slurry.

2) Salt water base slurry: Add 40 g NaCl to 1000 mL of 4% sodium bentonite base slurry, stir at high speed for 5 minutes, and place at room temperature for 24 hours to obtain salt water base slurry.

3) Saturated brine base slurry: add 35% sodium chloride to 1000 mL of 4% bentonite fresh water base slurry, stir at high speed for 5 minutes, and place at room temperature for 24 hours to obtain saturated brine base slurry.

4) Composite salt water-based slurry: add 15.75g sodium chloride, 2.62g anhydrous calcium chloride, 6.9g magnesium chloride, 52.5g calcium bentonite and 3.15g anhydrous sodium carbonate to 350mL distilled water, stir at high speed for 20min, and place it at room temperature for aging for 24h , to obtain a composite brine-based slurry.

Embodiment 6 and comparative example 6

Embodiment 6 and comparative example 6 have listed the impact of different additions of SM-4 polymers on the performance of different types of drilling fluids, wherein embodiment 6a and comparative example 6a are the effects of different additions of SM-4 polymers on the performance of freshwater drilling fluids Influence, embodiment 6b and comparative example 6b are the effects of different additions of SM-4 polymers on the performance of brine drilling fluids, and embodiment 6c and comparative example 6c are the effects of different additions of SM-4 polymers on the performance of saturated brine drilling fluids , Example 6d and Comparative Example 6d are the effects of different additions of SM-4 polymer on the performance of the composite brine drilling fluid.

Table 1 shows the effect of different additions of SM-4 polymer on the performance of freshwater drilling fluid.

Table 1

Amount added (wt%) FL/mL AV/mPa.s PV/mPa.s YP/Pa Comparative Example 6a-1 0 17 15 4 11 Example 6a-1 0.1 7.2 twenty two 14 8 Example 6a-2 0.3 7.0 39 17 twenty two Example 6a-3 0.5 5.2 69 34 35

It can be seen from Table 1 that SM-4 has a strong fluid loss reducing effect in freshwater drilling fluid, and when the addition amount is 0.1%, the fluid loss (FL) of drilling fluid can be significantly reduced (less than 10mL). As for the viscosity and shear force of drilling fluid, with the increase of its dosage, the viscosity (AV and PV) and shear force (YP) of drilling fluid both increase significantly, showing a strong ability to increase viscosity and shear, and From the experimental results, the addition of SM-4 improves the shear thinning properties of the drilling fluid.

Table 2 shows the effect of different additions of SM-4 polymer on the performance of brine drilling fluid.

Table 2

Amount added (wt%) FL/mL AV/mPa.s PV/mPa.s YP/Pa Comparative example 6b-1 0 84 4.5 2 2.5 Example 6b-1 0.3 8.2 10 7 3 Example 6b-2 0.5 6.6 15 11 4 Example 6b-3 0.7 4.2 twenty four 18 6 Example 6b-4 1.0 3.4 35 twenty four 11

It can be seen from Table 2 that SM-4 has a strong fluid loss reducing effect in brine drilling fluid. When the dosage is 0.3%, the fluid loss of drilling fluid can be significantly reduced, and it shows a strong Lifting ability.

Table 3 shows the effect of different additions of SM-4 polymer on the performance of saturated brine drilling fluid.

table 3

Amount added (wt%) FL/mL AV/mPa.s PV/mPa.s YP/Pa Comparative example 6c-1 0 134 6 4 2 Example 6c-1 0.5 11.0 13 9 4 Example 6c-2 0.7 8.6 15 10 5 Example 6c-3 1.0 6.0 19 12 7 Example 6c-4 1.5 3.4 twenty four 15 9

It can be seen from Table 3 that SM-4 has a strong fluid loss reducing effect in saturated brine drilling fluid. increasing and then gradually decreasing, while the viscosity of the drilling fluid also gradually increased.

Table 4 shows the experimental results of the effects of different additions of SM-4 polymer on the performance of the composite brine drilling fluid.

Table 4

Amount added (wt%) FL/mL AV/mPa.s PV/mPa.s YP/Pa Comparative example 6d-1 0 84 8 4 4 Example 6d-1 0.5 6.6 11 6 5 Example 6d-2 0.7 6.0 13 7 6 Example 6d-3 1.0 4.8 20 13 7 Example 6d-4 1.5 3.6 28 19 9

It can be seen from Table 4 that SM-4 has a strong fluid loss reducing effect in the composite brine drilling fluid. When the amount is added at 0.5%, the fluid loss of the drilling fluid can be reduced to less than 10mL, and it shows a relatively good performance. Strong lifting ability.

Example 7

Example 7 lists the temperature resistance test results of the polymer additive SM-4 obtained in Example 1. Wherein embodiment 7a is the influence of SM-4 on the performance of fresh water slurry, embodiment 7b is the influence of SM-4 on the performance of brine drilling fluid, embodiment 7c is the influence of SM-4 on the performance of saturated brine drilling fluid, and embodiment 7d is The effect of SM-4 on the performance of composite brine drilling fluid.

Table 5 shows the temperature resistance test results of different drilling fluids treated with SM-4, where the corresponding aging time is 16h when the aging temperature is 180°C; 1.0wt%, 1.5wt% and 1.5wt%, each room temperature is the same as the amount of polymer additive used in the corresponding 180°C experiment.

table 5

Aging temperature (°C) FL/mL AV/mPa.s PV/mPa.s YP/Pa Example 7a-1 room temperature 5.2 69 34 35 Example 7a-2 180 3.2 twenty four 19 5 Example 7b-1 room temperature 3.4 35 twenty four 11 Example 7b-2 180 1.6 9 5 4 Example 7c-1 room temperature 3.4 twenty four 15 9 Example 7c-2 180 7.0 8 4 4 Example 7d-1 room temperature 3.6 28 19 9 Example 7d-2 180 8.4 5 3 2

It can be seen from Table 5 that after treatment with SM-4, the fluid loss of various drilling fluids changes little before and after aging at 180°C, indicating that SM-4 has a strong temperature resistance.

Embodiment 8 and comparative example 8

Example 8 lists the comparative experimental results of polymer additive SM-4 obtained in Example 1 and commonly used polymer treatment agents SD-17W, MAN-101, and SL-1 in oil drilling sites in saturated brine drilling fluid. Among them, comparative example 8a is the detection result of saturated brine drilling fluid without any additives, comparative example 8b is the detection result of adding 2wt% additive SD-17W in saturated brine drilling fluid, and comparative example 8c is the detection result of saturated brine drilling fluid adding 2wt% additive MAN-101 detection result, comparative example 8d is the detection result of adding 2wt% additive SL-1 in saturated brine drilling fluid, embodiment 8a is adding 2wt% additive in the present invention in saturated brine drilling fluid SM-4 test results. In addition, those skilled in the art know that SD-17W, MAN-101 and SL-1 are all organic monomer polymer additives, which do not contain inorganic substances.

Table 6 lists the comparative experimental results of different polymer additives in saturated brine drilling fluid, wherein the data are all obtained after aging at 180° C. for 16 hours.

Table 6

FL/mL AV/mPa.s PV/mPa.s YP/Pa Comparative Example 8a 228 5 4 1 Comparative Example 8b 86 11 10 1 Comparative example 8c 50 17 14 3 Comparative example 8d 45 15 12 3 Example 8a 6 9 5 4

It can be seen from Table 6 that SM-4 has a strong ability to resist heat and salt. When the dosage is 2%, its fluid loss reduction effect is better than that of polymer treatment agents SD-17W and MAN- 101 and SL-1.

Embodiment 9 and comparative example 9

Example 9 lists the effect of the polymer additive SM-4 obtained in Example 1 in well fluid polluted by saturated brine. Among them, comparative example 9a is the test result of the well mud of Pushen 28 well in Zhongyuan Oilfield with a depth of 2670m, and comparative example 9b is the test result of the well mud contaminated by salt water obtained after mixing saturated brine into the above well mud at a ratio of 1:1. Example 9a is the test result after adding the additive SM-4 of the present invention to the above-mentioned well mud contaminated by brine, wherein the addition of SM-4 in Example 9a-1 is 0.3wt%, while in Example 9a-2 The addition amount of SM-4 is 0.5wt%, and the experimental results obtained are shown in Table 7.

Table 7

FL/mL AV/mPa.s PV/mPa.s YP/Pa Comparative Example 9a 3 52.5 30 22.5 Comparative Example 9b 12.2 31 2 29 Example 9a-1 5.2 54 19 35 Example 9a-2 2.8 73 28 45

It can be seen from Table 7 that the fluid loss of the drilling fluid decreased significantly after adding SM-4, and the fluid loss reduction effect increased with the increase of its dosage, indicating that SM-4 has good compatibility with the field drilling fluid and can Good control of the phenomenon of increased fluid loss after well mud pollution.

Embodiment 10 and comparative example 10

Example 10 and Comparative Example 10 list the apparent viscosities of 1% aqueous solutions of different polymers and their performance test results in composite brine drilling fluids. Wherein comparative example 10a is the organic polymer treating agent obtained in comparative example 1 used, comparative example 10b is the treating agent obtained in comparative example 2 used, and comparative example 10c is the treating agent obtained in the prior art CN200710180495.0 used, implemented Example 10a is the treatment agent SM-4 obtained in Example 1 used, and Example 10b is the additive obtained in Example 3 used. Table 8 shows the experimental results of the apparent viscosity of 1% aqueous solutions of different polymers and the properties of the composite brine drilling fluid.

Table 8

As can be seen from Table 8, first of all, the apparent viscosities of the 1% aqueous solution of the polymer obtained in Example 1 and the polymer obtained in Example 3 are equivalent and significantly higher than that of Comparative Example 1, Comparative Example 2 and prior art CN200710180495.0 The apparent viscosity of the 1% aqueous solution of the treatment agent in

Secondly, from the comparison of Example 10 (including Examples 10a and 10b) and Comparative Example 10a, it can be seen that the treatment agent of the present invention has a better fluid loss reducing effect in drilling fluid, and a better viscosity-shear improving ability. This shows that the inorganic-organic polymer treatment agent prepared by the present invention can achieve a comparable or even better effect than the pure organic polymer treatment agent while saving costs.

And from the comparative illustration of embodiment 10 and comparative example 10b, in comparative example 2, after obtaining organic polymer treatment agent, the scheme that inorganic material is mixed in can not form the inorganic-organic polymer treatment agent similar among the present invention, to The treatment agent corresponding to ratio 2 has poor performance in terms of fluid loss reduction effect and viscoshear enhancement ability.

In addition, it can be seen from the comparison between Comparative Example 10c and Comparative Example 10a that no matter in terms of fluid loss or viscous shear performance, the degree of improvement is not obvious; and from the comparison between Example 10 and Comparative Example 10c, no matter in terms of fluid loss Both the amount and the sticking performance have been greatly improved in Example 10.

The embodiments and application effects of the present invention have been described in detail above. However, the present invention is not limited to the specific details in the above embodiments. Within the scope of the technical concept of the present invention, various simple modifications can be made to the technical solutions of the present invention. These Simple modifications all belong to the protection scope of the present invention. In addition, it should be noted that the various specific technical features described in the above specific implementation manners may be combined in any suitable manner if there is no contradiction. In order to avoid unnecessary repetition, various possible combinations are not further described in the present invention. In addition, various combinations of different embodiments of the present invention can also be combined arbitrarily, as long as they do not violate the idea of the present invention, they should also be regarded as the disclosed content of the present invention.

Claims (10)

1. a drilling fluid inorganic-organic polymer treatment agent, is characterized in that, described treatment agent is be polymerized under the effect of initiator by sulfonic acid monomer, carboxylic acid monomer, non-ionic monomer and inorganic materials to be formed; And comprise wilkinite in described inorganic materials.

2. treatment agent according to claim 1, it is characterized in that, described sulfonic acid monomer is selected from 2-acrylamide-2-methyl propane sulfonic, 2-acryloxy-2-methyl propane sulfonic acid, acryloyl-oxy fourth sulfonic acid, 2-acrylamide-2-Phenyl-ethanesulfonic acid and 2-acrylamide dodecyl sodium sulfonate, described carboxylic acid monomer is selected from vinylformic acid, methacrylic acid, methylene-succinic acid and toxilic acid, described non-ionic monomer is selected from acrylamide, N,N-DMAA, isobutyl-acrylamide and vinyl cyanide.

3. treatment agent according to claim 1, it is characterized in that, described initiator is the oxidation-reduction trigger system comprising Oxidizing and Reducing Agents, wherein oxygenant is selected from Potassium Persulphate, ammonium persulphate and Sodium Persulfate, and reductive agent is selected from sodium bisulfite, S-WAT, Sulfothiorine, Sodium Pyrosulfite, ferrous sulfate and iron protochloride.

4. according to the treatment agent in claims 1 to 3 described in any one, it is characterized in that, also comprise in silicon magnesium gel, lithium magnesium silicate inorganic gel, aluminium magensium silicate inorganic gel, aluminium triphosphate, sepiolite and attapulgite in described inorganic materials one or more, wilkinite in preferred described inorganic materials accounts for more than the 50wt% of the total mass of inorganic materials, more preferably more than 80wt%.

5., as a preparation method for treatment agent as described in any one in Claims 1 to 4, comprise the steps:

1) in containing the aqueous solution of alkali, inorganic materials is added, grind with colloidal mill after stirring, in the mixed solution after grinding, sulfonic acid monomer and carboxylic acid monomer is added be no more than the condition of 35 DEG C in temperature under, continue stirring and add non-ionic monomer wherein again after 1 minute ~ 3 hours, then obtain reaction mixture after continuing stirring 1 minute ~ 5 hours;

2) by step 1) reaction mixture of gained inserts in polymerization reaction vessel, and selectively continue stirring 1 ~ 30 minute, with alkali, solution ph is adjusted to 8 ~ 11, add initiator, and the starting temperature controlling polyreaction is 35 ~ 50 DEG C, reacts 2 ~ 24 hours, obtain gum-like product; Also pulverize by dry for products therefrom and obtain described treatment agent.

6. preparation method according to claim 5, it is characterized in that, inorganic materials described in the raw material used before polyreaction account for sulfonic acid monomer, carboxylic acid monomer, non-ionic monomer and inorganic materials the mass percent of total mass be 5 ~ 25%, be preferably 10 ~ 20%.

7. preparation method according to claim 5, is characterized in that, step 1) in sulfonic acid monomer, amount of substance between carboxylic acid monomer and non-ionic monomer ratio be 10 ~ 40:10 ~ 25:80 ~ 35.

8. preparation method according to claim 5, is characterized in that, step 1) reaction mixture in the consumption of water be control the quality that the total mass of reaction raw materials is reaction mixture 40 ~ 60%.

9. preparation method according to claim 5, is characterized in that, the consumption of described initiator is 0.2 ~ 0.75wt% of sulfonic acid monomer, carboxylic acid monomer and non-ionic monomer total mass, and the mass ratio of described oxygenant and described reductive agent is 1:1 ~ 2.5.

10., according to the preparation method in claim 5 ~ 9 described in any one, it is characterized in that, step 1) in the ratio of the amount of substance of alkali used and the amount of substance sum of described carboxylic acid monomer and sulfonic acid monomer be 1:0.9 ~ 1.1, be preferably 1:1.