CN113563539B - Water-based drilling fluid surface hydration inhibitor and preparation method and application thereof - Google Patents
Water-based drilling fluid surface hydration inhibitor and preparation method and application thereof Download PDFInfo
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- 239000012530 fluid Substances 0.000 title claims abstract description 51
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- 239000000178 monomer Substances 0.000 claims abstract description 37
- 238000003756 stirring Methods 0.000 claims abstract description 30
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- 239000003054 catalyst Substances 0.000 claims abstract description 12
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- XFTALRAZSCGSKN-UHFFFAOYSA-M sodium;4-ethenylbenzenesulfonate Chemical compound [Na+].[O-]S(=O)(=O)C1=CC=C(C=C)C=C1 XFTALRAZSCGSKN-UHFFFAOYSA-M 0.000 claims description 8
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- 239000000203 mixture Substances 0.000 claims description 7
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- FEQPHYCEZKWPNE-UHFFFAOYSA-K trichlororhodium;triphenylphosphane Chemical compound Cl[Rh](Cl)Cl.C1=CC=CC=C1P(C=1C=CC=CC=1)C1=CC=CC=C1 FEQPHYCEZKWPNE-UHFFFAOYSA-K 0.000 claims description 7
- VFRQEVIIBMUKCQ-UHFFFAOYSA-M ethyl-dimethyl-(2-prop-2-enoyloxyethyl)azanium;chloride Chemical compound [Cl-].CC[N+](C)(C)CCOC(=O)C=C VFRQEVIIBMUKCQ-UHFFFAOYSA-M 0.000 claims description 6
- SMZOUWXMTYCWNB-UHFFFAOYSA-N 2-(2-methoxy-5-methylphenyl)ethanamine Chemical compound COC1=CC=C(C)C=C1CCN SMZOUWXMTYCWNB-UHFFFAOYSA-N 0.000 claims description 5
- NIXOWILDQLNWCW-UHFFFAOYSA-N 2-Propenoic acid Natural products OC(=O)C=C NIXOWILDQLNWCW-UHFFFAOYSA-N 0.000 claims description 5
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- 125000003903 2-propenyl group Chemical group [H]C([*])([H])C([H])=C([H])[H] 0.000 claims description 4
- AVWKSSYTZYDQFG-UHFFFAOYSA-M dimethyl-octadecyl-prop-2-enylazanium;chloride Chemical compound [Cl-].CCCCCCCCCCCCCCCCCC[N+](C)(C)CC=C AVWKSSYTZYDQFG-UHFFFAOYSA-M 0.000 claims description 4
- 238000009775 high-speed stirring Methods 0.000 claims description 4
- XHZPRMZZQOIPDS-UHFFFAOYSA-N 2-Methyl-2-[(1-oxo-2-propenyl)amino]-1-propanesulfonic acid Chemical compound OS(=O)(=O)CC(C)(C)NC(=O)C=C XHZPRMZZQOIPDS-UHFFFAOYSA-N 0.000 claims description 3
- CERQOIWHTDAKMF-UHFFFAOYSA-N Methacrylic acid Chemical compound CC(=C)C(O)=O CERQOIWHTDAKMF-UHFFFAOYSA-N 0.000 claims description 3
- 230000008569 process Effects 0.000 claims description 3
- 238000012360 testing method Methods 0.000 claims description 3
- 125000005394 methallyl group Chemical group 0.000 claims description 2
- QBERHIJABFXGRZ-UHFFFAOYSA-M rhodium;triphenylphosphane;chloride Chemical group [Cl-].[Rh].C1=CC=CC=C1P(C=1C=CC=CC=1)C1=CC=CC=C1.C1=CC=CC=C1P(C=1C=CC=CC=1)C1=CC=CC=C1.C1=CC=CC=C1P(C=1C=CC=CC=1)C1=CC=CC=C1 QBERHIJABFXGRZ-UHFFFAOYSA-M 0.000 claims description 2
- 239000011995 wilkinson's catalyst Substances 0.000 claims description 2
- 239000011435 rock Substances 0.000 abstract description 7
- 230000002401 inhibitory effect Effects 0.000 abstract description 3
- 230000009286 beneficial effect Effects 0.000 abstract description 2
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- DZSVIVLGBJKQAP-UHFFFAOYSA-N 1-(2-methyl-5-propan-2-ylcyclohex-2-en-1-yl)propan-1-one Chemical compound CCC(=O)C1CC(C(C)C)CC=C1C DZSVIVLGBJKQAP-UHFFFAOYSA-N 0.000 description 1
- 229920000536 2-Acrylamido-2-methylpropane sulfonic acid Polymers 0.000 description 1
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Classifications
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- C—CHEMISTRY; METALLURGY
- C08—ORGANIC MACROMOLECULAR COMPOUNDS; THEIR PREPARATION OR CHEMICAL WORKING-UP; COMPOSITIONS BASED THEREON
- C08F—MACROMOLECULAR COMPOUNDS OBTAINED BY REACTIONS ONLY INVOLVING CARBON-TO-CARBON UNSATURATED BONDS
- C08F283/00—Macromolecular compounds obtained by polymerising monomers on to polymers provided for in subclass C08G
- C08F283/06—Macromolecular compounds obtained by polymerising monomers on to polymers provided for in subclass C08G on to polyethers, polyoxymethylenes or polyacetals
- C08F283/065—Macromolecular compounds obtained by polymerising monomers on to polymers provided for in subclass C08G on to polyethers, polyoxymethylenes or polyacetals on to unsaturated polyethers, polyoxymethylenes or polyacetals
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/02—Well-drilling compositions
- C09K8/03—Specific additives for general use in well-drilling compositions
- C09K8/035—Organic additives
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/02—Well-drilling compositions
- C09K8/04—Aqueous well-drilling compositions
- C09K8/14—Clay-containing compositions
- C09K8/18—Clay-containing compositions characterised by the organic compounds
- C09K8/22—Synthetic organic compounds
- C09K8/24—Polymers
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- Chemical & Material Sciences (AREA)
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- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
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- Health & Medical Sciences (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Medicinal Chemistry (AREA)
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Abstract
The invention provides a preparation method of a water-based drilling fluid surface hydration inhibitor, which comprises the following steps: 1) Mixing and co-dissolving polyether monomer containing unsaturated bond, hydrophilic monomer, cationic monomer and temperature-resistant monomer with rigid group in tetrahydrofuran to obtain mixed solution A; 2) Slowly adding a proper amount of methyl hydrogen-containing silicone oil into the mixed solution A, and stirring the mixed solution A at a low speed during the period to obtain a mixed solution B; the low-speed stirring rotating speed is 1000r/min; 3) Adding a proper amount of catalyst into the mixed solution B in an inert atmosphere, and reacting at 40-50 ℃ while stirring; 4) And removing the solvent tetrahydrofuran after the reaction is finished to obtain the surface hydration inhibitor. The invention also provides a water-based drilling fluid surface hydration inhibitor prepared based on the preparation method and application thereof. The water-based drilling fluid surface hydration inhibitor provided by the invention is high-temperature resistant and is beneficial to inhibiting hydration of the drilling well wall rock argillaceous components.
Description
Technical Field
The invention relates to the technical field of petroleum drilling, in particular to a water-based drilling fluid surface hydration inhibitor and application thereof.
Background
About 75% of formations traversed during drilling are shale, while about 90% of wellbore instability problems occur in shale formations. Shale borehole wall stabilization has long been a worldwide challenge in oil and gas well engineering. Through the years of efforts of students and engineering technicians at home and abroad, the method for recognizing the well instability mechanism, evaluating the shale instability, developing shale inhibitors, formulating anti-collapse drilling fluid technical countermeasures and the like, although the method has made great progress, the problem of the well instability of complex shale stratum is not solved.
The main components of the shale stratum are various clay minerals, and various clay minerals can absorb water and expand, but the degree of hydration expansion of different clay minerals is different due to different structures. Clay hydration expansion is limited by three forces, namely surface hydration, osmotic hydration and capillary action. The surface hydration is caused by the adsorption of water molecules and exchangeable cations on the surface of the clay crystal, is the first stage of the clay hydration, causes small expansion amount, but has very large expansion pressure, and is a factor which cannot be ignored in the instability of the well wall.
Shale inhibitors can reduce the hydration degree of shale, are important additives in drilling fluid for stabilizing the well wall, and can be used in fracturing fluid and acidizing fluid. Traditional shale inhibitors such as inorganic salts, organic salts, polyalcohols, asphalt and the like are still widely used, and the novel amino inhibitors have outstanding application effects in high-performance water-based drilling fluid and are increasingly researched and applied. Shale inhibitors of the plant extract, nanomaterial, etc. type have also attracted attention by researchers. The hydrophilicity of the shale surface is a significant cause of its surface hydration. Most shale inhibitor at present can not solve the problem of hydrophilicity of the shale surface, inhibit shale surface hydration performance weak, be difficult to form effective hydrophobic layer on the rock surface, lead to partial complicated shale stratum wall instability still serious. In addition, shale inhibitors have poor temperature resistance, are easy to decompose and lose efficacy under high temperature conditions, and are difficult to effectively act on high temperature deep strata.
Disclosure of Invention
Aiming at the technical problems to be solved, such as weak hydration performance of the shale surface, difficult formation of an effective hydrophobic layer, poor temperature resistance and the like, the invention provides a water-based drilling fluid surface hydration inhibitor of modified silicone oil.
The invention provides modified silicone oil which can effectively form a film on the surface of shale, and form an effective hydrophobic layer on the surface of the shale, so that the wettability of the clay surface is changed from hydrophile to hydrophobe, the free energy of the rock surface is reduced, the adsorption of water molecules on the clay mineral surface is greatly prevented or weakened, and the effect of inhibiting the hydration of the clay surface is achieved.
The invention firstly provides a preparation method of a water-based drilling fluid surface hydration inhibitor, which comprises the following steps:
1) Mixing and co-dissolving polyether monomer containing unsaturated bond, hydrophilic monomer, cationic monomer and temperature-resistant monomer with rigid group in tetrahydrofuran to obtain mixed solution A;
2) Slowly adding a proper amount of methyl hydrogen-containing silicone oil into the mixed solution A, and stirring the mixed solution A at a low speed during the period to obtain a mixed solution B; the low-speed stirring rotating speed is 1000r/min;
3) Adding a proper amount of catalyst into the mixed solution B in an inert atmosphere, and reacting at 40-50 ℃ while stirring;
4) Removing solvent tetrahydrofuran after the reaction is finished to obtain a surface hydration inhibitor;
wherein,
the polyether monomer is one of Allyl Polyoxyethylene Ether (APEG) or methallyl polyoxyethylene ether (TPEG);
the hydrophilic monomer is selected from one of acrylamide, acrylic acid and methacrylic acid, or two or more of the hydrophilic monomers mixed in any proportion;
the cationic monomer is selected from one of dimethyl diallyl ammonium chloride (DMDAAC), methyl-acryloyloxyethyl trimethyl ammonium chloride (DMC) or octadecyl dimethyl allyl ammonium chloride;
the temperature resistant monomer with the rigid group is one or more of 2-acrylamido-2-methylpropanesulfonic Acid (AMPS), sodium p-styrenesulfonate (SSS) and styrene (St);
the catalyst is a Wilkinson catalyst triphenylphosphine rhodium chloride.
In one embodiment according to the invention, the stirring and reaction temperature is kept constant for a period of 4 to 6 hours.
In one embodiment according to the invention, the mass ratio of polyether monomer, hydrophilic monomer, cationic monomer, temperature resistant monomer and catalyst is 100 to 120:50-60:30-40:50-60:1.
in one embodiment according to the invention, the volume ratio of methyl hydrogen silicone oil to mixed liquor a is 1-2:2-3.
In one embodiment according to the invention, the inert atmosphere is achieved by introducing nitrogen into the reaction vessel; preferably, the nitrogen is dry anhydrous.
In one embodiment according to the invention, the solvent tetrahydrofuran is removed by a rotary evaporator or nitrogen blower.
The invention also provides the water-based drilling fluid surface hydration inhibitor prepared according to the preparation method.
The water-based drilling fluid surface hydration inhibitor is white viscous liquid.
The invention further provides a water-based drilling fluid which contains the water-based drilling fluid surface hydration inhibitor.
Preferably, the bentonite-based slurry contains 4% of bentonite-based slurry and 2% of water-based drilling fluid surface hydration inhibitor in volume fraction;
preferably, the bentonite-based slurry is formulated by a process comprising the steps of:
under the condition of high-speed stirring, bentonite and sodium carbonate for slurry preparation in a drilling fluid test are dissolved in water, the mixture is stirred at a high speed for 20min, and the mixture is maintained in a sealed mode for 24h at 25 ℃, so that the drilling fluid is obtained, wherein the ratio of the bentonite to the sodium carbonate is mL: g: the ratio of water, bentonite and sodium carbonate is 500:20:1.
the invention utilizes the principle of hydrosilylation reaction to synthesize the surface hydration inhibitor modified silicone oil for the water-based drilling fluid. In order to solve the problems, the defects of the existing surface hydration inhibitor are overcome from three aspects. Methyl hydrogen silicone oil is selected as a main body, so that the hydrophobic effect is good, and the hydrophobic effect is easy to modify. The polyether monomer and the hydrophilic monomer containing unsaturated bonds are introduced, so that the defect of difficult dispersion in the water-based drilling fluid caused by over-strong hydrophobicity is avoided. Meanwhile, the cationic monomer is introduced, so that the adsorption effect of the cationic monomer on the shale stratum is improved, and the residence effect of the hydration inhibitor on the shale surface is improved. Finally, introducing a temperature-resistant monomer with a rigid group, and improving the temperature-resistant effect of the temperature-resistant monomer on the deep stratum.
The technical scheme of the invention has the following beneficial effects:
the water-based drilling fluid surface hydration inhibitor provided by the invention has good stability of the well wall, forms a compact hydrophobic film on the well wall, can block water molecules from entering, and has good surface hydration inhibition effect.
Meanwhile, the water-based drilling fluid surface hydration inhibitor provided by the invention has a strong adsorption effect, and the cationic monomer is introduced, so that the binding force between the well wall and the stratum is improved, and the adsorption effect of the hydrophobic membrane is improved.
On the other hand, the water-based drilling fluid surface hydration inhibitor provided by the invention has high-temperature resistance. The material is not decomposed in a high-temperature environment, has excellent temperature resistance and can resist the high temperature of 180 ℃.
Detailed Description
In order to make the technical problems, technical solutions and advantages to be solved by the present invention more apparent, the following detailed description will be made with reference to specific embodiments.
Example 1: water-based drilling fluid surface hydration inhibitor 1#, and preparation method thereof
1) 10g of methyl allyl polyoxyethylene ether, 4g of acrylamide, 1g of acrylic acid, 3g of dimethyl diallyl ammonium chloride, 3g of 2-acrylamide-2-methylpropanesulfonic acid and 2g of sodium p-styrenesulfonate are added into 100ml of tetrahydrofuran, and the mixture is stirred and mixed uniformly to obtain a mixed solution A;
2) Placing the mixed solution A on a low-speed stirrer, keeping the stirring rotation speed at 1000r/min, and slowly adding 50ml of methyl hydrogen-containing silicone oil to obtain mixed solution B;
3) Transferring the mixed solution B into a three-neck flask with a double-exhaust vacuum system in a fume hood, deoxidizing by utilizing nitrogen, keeping stirring and heating to 45 ℃, adding 0.1g of catalyst triphenylphosphine rhodium chloride, and keeping anhydrous ventilation and introducing nitrogen in the whole reaction process.
4) The stirring and reaction temperature were kept constant and the reaction time was 5 hours.
5) After the reaction is finished, the mixed solution is moved to a rotary evaporator, and the tetrafluoro-hydrogen pyran is separated by rotary evaporation to obtain a reaction product.
The final product was a white viscous liquid.
Example 2: water-based drilling fluid surface hydration inhibitor No. 2
1. Adding 12g of allyl polyoxyethylene ether, 4g of acrylamide, 2g of methacrylic acid, 4g of methyl-acryloyloxyethyl trimethyl ammonium chloride and 6g of sodium p-styrenesulfonate into 75ml of tetrahydrofuran, and stirring and mixing uniformly to obtain a mixed solution A;
2. placing the mixed solution A on a low-speed stirrer, keeping the stirring rotation speed at 1000r/min, and slowly adding 50ml of methyl hydrogen-containing silicone oil to obtain mixed solution B;
3. transferring the mixed solution B into a three-neck flask with a double-exhaust vacuum system in a fume hood, deoxidizing by utilizing nitrogen, keeping stirring and heating to 50 ℃, adding 0.1g of catalyst triphenylphosphine rhodium chloride, and keeping anhydrous ventilation and introducing nitrogen in the whole reaction process.
4. The stirring and reaction temperature were kept constant and the reaction time was 4 hours.
5. After the reaction is finished, the mixed solution is moved to a rotary evaporator, and the tetrafluoro-hydrogen pyran is separated by rotary evaporation to obtain a reaction product.
The final product was a white viscous liquid.
Example 3: water-based drilling fluid surface hydration inhibitor 3#
1. Adding 12g of methyl allyl polyoxyethylene ether, 3g of acrylic acid, 3g of acrylamide, 3g of octadecyl dimethyl allyl ammonium chloride, 3g of sodium p-styrene sulfonate and 2g of styrene into 100ml of tetrahydrofuran, and stirring and mixing uniformly to obtain a mixed solution A;
2. placing the mixed solution A on a low-speed stirrer, keeping the stirring rotation speed at 1000r/min, and slowly adding 50ml of methyl hydrogen-containing silicone oil to obtain mixed solution B;
3. transferring the mixed solution B into a three-neck flask with a double-exhaust vacuum system in a fume hood, deoxidizing by using nitrogen, keeping stirring and heating to 40 ℃, adding 0.1g of catalyst triphenylphosphine rhodium chloride, and keeping anhydrous ventilation and introducing nitrogen in the whole reaction process.
4. The stirring and reaction temperature were kept constant and the reaction time was 6 hours.
5. After the reaction is finished, the mixed solution is moved to a rotary evaporator, and the tetrafluoro-hydrogen pyran is separated by rotary evaporation to obtain a reaction product.
The final product was a white viscous liquid.
Example 4: water-based drilling fluid surface hydration inhibitor 4#, and preparation method thereof
1. 11g of allyl polyoxyethylene ether, 3g of acrylamide, 3g of acrylic acid, 3.5g of octadecyl dimethyl allyl ammonium chloride and 5g of sodium p-styrenesulfonate are added into 75ml of tetrahydrofuran, and the mixture is stirred and mixed uniformly to obtain a mixed solution A;
2. placing the mixed solution A on a low-speed stirrer, keeping the stirring rotation speed at 1000r/min, and slowly adding 50ml of methyl hydrogen-containing silicone oil to obtain mixed solution B;
3. transferring the mixed solution B into a three-neck flask with a double-exhaust vacuum system in a fume hood, deoxidizing by utilizing nitrogen, keeping stirring and heating to 50 ℃, adding 0.1g of catalyst triphenylphosphine rhodium chloride, and keeping anhydrous ventilation and introducing nitrogen in the whole reaction process.
4. The stirring and reaction temperature were kept constant and the reaction time was 4 hours.
5. After the reaction is finished, the mixed solution is moved to a rotary evaporator, and the tetrafluoro-hydrogen pyran is separated by rotary evaporation to obtain a reaction product.
The final product was a white viscous liquid.
Example 5: water-based drilling fluid surface hydration inhibitor No. 5
1. Adding 12g of methyl allyl polyoxyethylene ether, 5g of acrylamide, 3.5g of methyl-acryloyloxyethyl trimethyl ammonium chloride and 5g of 2-acrylamido-2-methylpropanesulfonic acid into 100ml of tetrahydrofuran, and uniformly stirring and mixing to obtain a mixed solution A;
2. placing the mixed solution A on a low-speed stirrer, keeping the stirring rotation speed at 1000r/min, and slowly adding 50ml of methyl hydrogen-containing silicone oil to obtain mixed solution B;
3. transferring the mixed solution B into a three-neck flask with a double-exhaust vacuum system in a fume hood, deoxidizing by utilizing nitrogen, keeping stirring and heating to 50 ℃, adding 0.1g of catalyst triphenylphosphine rhodium chloride, and keeping anhydrous ventilation and introducing nitrogen in the whole reaction process.
4. The stirring and reaction temperature were kept constant and the reaction time was 4 hours.
5. After the reaction is finished, the mixed solution is moved to a rotary evaporator, and the tetrafluoro-hydrogen pyran is separated by rotary evaporation to obtain a reaction product.
The final product was a white viscous liquid.
Example 6 evaluation of Performance of the Water-based drilling fluid surface hydration inhibitors prepared in examples 1-5
The modified silicone oils prepared in examples 1 to 5 were characterized and evaluated for properties as follows:
1. evaluation of hydrophobic Effect
The modified silicone oil surface hydration inhibitor is respectively prepared into 1% and 2% aqueous solutions by mass, and the cut original core slices (phi 25 multiplied by 3 mm) of the Lobster are added into the aqueous solutions. Aging for 16h at 180 ℃, and observing the condition of the hydrophobic layer of the core after drying. And meanwhile, measuring the water phase contact angle of the dried core surface.
TABLE 1 surface hydration inhibitor concentration and core contact angle relationship
| Concentration of surface hydration inhibitor | Core contact angle/° |
| 0 | 14.3 |
| 1% example 1 | 101 |
| 2% example 1 | 111 |
| 1% example 2 | 108 |
| 2% example 2 | 113 |
| 1% example 3 | 99 |
| 2% example 3 | 104 |
| 1% example 4 | 105 |
| 2% example 4 | 114 |
| 1% implementationExample 5 | 103 |
| 2% example 5 | 109 |
As can be seen from Table 1, after the modified silicone oil surface hydration inhibitor synthesized by the invention is aged at 180 ℃, a layer of hydrophobic material is adsorbed on the surface of the core slice, and a hydrophobic film is formed. As the concentration of the modified silicone oil increases, the shale surface contact angle also increases, but the magnitude of the increase is limited. The increase of the contact angle can reduce the free energy of the shale surface in theory, reduce the water adsorption capacity of the shale surface and achieve the effect of inhibiting the surface hydration.
2. Compatibility evaluation
Preparing bentonite-based slurry:
400mL of tap water is poured into a high-stirring cup, 16.0g of bentonite (meeting SY/T5490-2016) for drilling fluid test slurry preparation and 0.8g of sodium carbonate (chemical purity) are added under high-speed stirring, the high-speed stirring is carried out for 20min, and the sealing maintenance is carried out at 25 ℃ for 24h.
2% of example products are added into 4% of bentonite-based slurry prepared by the method, and rheological parameters and API (application program interface) fluid loss of drilling fluid are tested by referring to national standard GB/T29170-2012 drilling fluid laboratory test of petroleum and natural gas industry; aging for 16 hours at 180 ℃ by using a roller heating furnace, and measuring rheological parameters, API (application program interface) filter loss and high-temperature high-pressure filter loss of the drilling fluid.
Table 2 effect of example products on rheological properties of drilling fluids
TABLE 3 influence of example products on drilling fluid loss properties
As can be seen from Table 2, after the addition of the example product, there was substantially no adverse change in the rheological parameters of the drilling fluid before and after aging, compared with the base slurry, indicating that the example product of the present invention has excellent temperature resistance and no adverse effect on the rheological properties of the drilling fluid. As can be seen from table 3, the base slurry API fluid loss of the added example product did not significantly change adversely with respect to the bentonite base slurry. After high-temperature aging, the high-temperature high-pressure filtration loss of the base slurry added with the product of the embodiment is also reduced to a certain extent relative to the base slurry.
Therefore, the modified organic silicone oil surface hydration inhibitor can resist higher temperature and has little adverse effect on rheological parameters of drilling fluid.
3. Inhibition performance evaluation
Shale dispersion experiments at different temperatures are carried out by adopting Sichuan pine shale mud shale rock samples. The experimental steps are that 50g of shale rock sample with 6-10 meshes is added into 350ml of 2% modified organic silicone oil surface hydration inhibitor example solution, the rock sample is heated and rolled for 16 hours at 180 ℃, then the rock sample is washed by clean water and passes through a 40-target standard sieve, the remainder of the sieve is baked for 4 hours at 105 ℃, and then the recovery rate is calculated by weighing.
Table 4 example rolling recovery experiment
| Formulation of | Rolling recovery/% |
| Clean water | 7.0 |
| Clear water +2% example 1 | 83.5 |
| Clear water +2% example 2 | 84.0 |
| Clear water +2% example 3 | 84.8 |
| Clear water +2% example 4 | 82.7 |
| Clear water +2% example 5 | 85.1 |
As can be seen from Table 4, the modified silicone oil surface hydration inhibitor developed by the invention can still maintain higher rolling recovery rate after aging at 180 ℃ compared with clear water. The rolling recovery rate of the embodiment is above 80%, which shows that the invention can effectively inhibit surface hydration, has good shale inhibition effect and improves the stability of the well wall during drilling. Meanwhile, the invention also shows that the shale hydration inhibition agent has good temperature resistance effect and good shale hydration inhibition effect after aging at 180 ℃.
While the foregoing is directed to the preferred embodiments of the present invention, it will be appreciated by those skilled in the art that various modifications and adaptations can be made without departing from the principles of the present invention, and such modifications and adaptations are intended to be comprehended within the scope of the present invention.
Claims (10)
1. A method for preparing a water-based drilling fluid surface hydration inhibitor, which is characterized by comprising the following steps:
1) Mixing and co-dissolving polyether monomer containing unsaturated bond, hydrophilic monomer, cationic monomer and temperature-resistant monomer with rigid group in tetrahydrofuran to obtain mixed solution A;
2) Slowly adding a proper amount of methyl hydrogen-containing silicone oil into the mixed solution A, and stirring the mixed solution A at a low speed during the period to obtain a mixed solution B; the low-speed stirring rotating speed is 1000r/min;
3) Adding a proper amount of catalyst into the mixed solution B in an inert atmosphere, and reacting at 40-50 ℃ while stirring;
4) Removing solvent tetrahydrofuran after the reaction is finished to obtain a surface hydration inhibitor;
the mass ratio of the polyether monomer to the hydrophilic monomer to the cationic monomer to the temperature-resistant monomer to the catalyst is 100-120:50-60:30-40:50-60:1, a step of;
the volume ratio of methyl hydrogen silicone oil to the mixed solution A is 1-2:2-3;
wherein,
the polyether monomer is one of Allyl Polyoxyethylene Ether (APEG) or methallyl polyoxyethylene ether (TPEG);
the hydrophilic monomer is selected from one of acrylamide, acrylic acid and methacrylic acid, or two or more of the hydrophilic monomers mixed in any proportion;
the cationic monomer is selected from one of dimethyl diallyl ammonium chloride (DMDAAC), methyl-acryloyloxyethyl trimethyl ammonium chloride (DMC) or octadecyl dimethyl allyl ammonium chloride;
the temperature resistant monomer with the rigid group is one or more of 2-acrylamido-2-methylpropanesulfonic Acid (AMPS), sodium p-styrenesulfonate (SSS) and styrene (St);
the catalyst is a Wilkinson catalyst triphenylphosphine rhodium chloride.
2. The process according to claim 1, wherein the stirring and the reaction temperature are kept constant for a period of 4 to 6 hours.
3. The process according to claim 1, wherein the inert atmosphere is achieved by introducing nitrogen into the reaction vessel.
4. The method of claim 3, wherein the nitrogen is dry anhydrous.
5. The method of claim 1, wherein the solvent tetrahydrofuran is removed by a rotary evaporator or nitrogen blower.
6. A water-based drilling fluid surface hydration inhibitor prepared by the method of any one of claims 1-5.
7. The water-based drilling fluid surface hydration inhibitor of claim 6, wherein said water-based drilling fluid surface hydration inhibitor is a white viscous liquid.
8. A water-based drilling fluid comprising the use of the water-based drilling fluid surface hydration inhibitor of claim 6 or 7 for the preparation of a drilling fluid.
9. The water-based drilling fluid of claim 8, comprising 4% bentonite-based slurry and 2% water-based drilling fluid surface hydration inhibitor by volume fraction.
10. The water-based drilling fluid of claim 9, wherein the bentonite-based slurry is formulated by a method comprising the steps of:
under the condition of high-speed stirring, bentonite and sodium carbonate for slurry preparation in a drilling fluid test are dissolved in water, the mixture is stirred at a high speed for 20min, and the mixture is maintained in a sealed mode for 24h at 25 ℃, so that the drilling fluid is obtained, wherein the ratio of the bentonite to the sodium carbonate is mL: g: the ratio of water, bentonite and sodium carbonate is 500:20:1.
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