CN115677900A - High-temperature high-density saturated salt water drilling fluid and preparation method thereof - Google Patents
High-temperature high-density saturated salt water drilling fluid and preparation method thereof Download PDFInfo
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- CN115677900A CN115677900A CN202211380678.8A CN202211380678A CN115677900A CN 115677900 A CN115677900 A CN 115677900A CN 202211380678 A CN202211380678 A CN 202211380678A CN 115677900 A CN115677900 A CN 115677900A
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- 238000005553 drilling Methods 0.000 title claims abstract description 84
- 239000012530 fluid Substances 0.000 title claims abstract description 77
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- 238000002360 preparation method Methods 0.000 title claims abstract description 31
- 229920006395 saturated elastomer Polymers 0.000 title claims abstract description 13
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- TZCXTZWJZNENPQ-UHFFFAOYSA-L barium sulfate Chemical compound [Ba+2].[O-]S([O-])(=O)=O TZCXTZWJZNENPQ-UHFFFAOYSA-L 0.000 claims description 35
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- 239000003638 chemical reducing agent Substances 0.000 claims description 32
- 238000003756 stirring Methods 0.000 claims description 27
- 239000000706 filtrate Substances 0.000 claims description 24
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 claims description 23
- WHNWPMSKXPGLAX-UHFFFAOYSA-N N-Vinyl-2-pyrrolidone Chemical compound C=CN1CCCC1=O WHNWPMSKXPGLAX-UHFFFAOYSA-N 0.000 claims description 22
- GQOKIYDTHHZSCJ-UHFFFAOYSA-M dimethyl-bis(prop-2-enyl)azanium;chloride Chemical compound [Cl-].C=CC[N+](C)(C)CC=C GQOKIYDTHHZSCJ-UHFFFAOYSA-M 0.000 claims description 22
- 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 22
- 239000000047 product Substances 0.000 claims description 20
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical compound [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 claims description 18
- 239000003795 chemical substances by application Substances 0.000 claims description 18
- ROOXNKNUYICQNP-UHFFFAOYSA-N ammonium persulfate Chemical compound [NH4+].[NH4+].[O-]S(=O)(=O)OOS([O-])(=O)=O ROOXNKNUYICQNP-UHFFFAOYSA-N 0.000 claims description 16
- 239000000203 mixture Substances 0.000 claims description 15
- 229920000536 2-Acrylamido-2-methylpropane sulfonic acid Polymers 0.000 claims description 13
- 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 13
- 239000008186 active pharmaceutical agent Substances 0.000 claims description 13
- 238000000034 method Methods 0.000 claims description 11
- 239000000178 monomer Substances 0.000 claims description 11
- CSCPPACGZOOCGX-UHFFFAOYSA-N Acetone Chemical compound CC(C)=O CSCPPACGZOOCGX-UHFFFAOYSA-N 0.000 claims description 10
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 10
- 239000000440 bentonite Substances 0.000 claims description 10
- 229910000278 bentonite Inorganic materials 0.000 claims description 10
- SVPXDRXYRYOSEX-UHFFFAOYSA-N bentoquatam Chemical compound O.O=[Si]=O.O=[Al]O[Al]=O SVPXDRXYRYOSEX-UHFFFAOYSA-N 0.000 claims description 10
- 239000003223 protective agent Substances 0.000 claims description 10
- 239000011780 sodium chloride Substances 0.000 claims description 10
- 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 claims description 9
- 229910000029 sodium carbonate Inorganic materials 0.000 claims description 9
- DWAQJAXMDSEUJJ-UHFFFAOYSA-M Sodium bisulfite Chemical compound [Na+].OS([O-])=O DWAQJAXMDSEUJJ-UHFFFAOYSA-M 0.000 claims description 8
- 229910001870 ammonium persulfate Inorganic materials 0.000 claims description 8
- 235000010267 sodium hydrogen sulphite Nutrition 0.000 claims description 8
- 238000006243 chemical reaction Methods 0.000 claims description 6
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims description 5
- 239000008367 deionised water Substances 0.000 claims description 5
- 229910021641 deionized water Inorganic materials 0.000 claims description 5
- 238000001035 drying Methods 0.000 claims description 5
- 239000003292 glue Substances 0.000 claims description 5
- 238000010438 heat treatment Methods 0.000 claims description 5
- 239000003999 initiator Substances 0.000 claims description 5
- 229910052757 nitrogen Inorganic materials 0.000 claims description 5
- 229920001495 poly(sodium acrylate) polymer Polymers 0.000 claims description 3
- NNMHYFLPFNGQFZ-UHFFFAOYSA-M sodium polyacrylate Chemical group [Na+].[O-]C(=O)C=C NNMHYFLPFNGQFZ-UHFFFAOYSA-M 0.000 claims description 3
- KXGFMDJXCMQABM-UHFFFAOYSA-N 2-methoxy-6-methylphenol Chemical compound [CH]OC1=CC=CC([CH])=C1O KXGFMDJXCMQABM-UHFFFAOYSA-N 0.000 claims description 2
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical group [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 claims description 2
- 238000013329 compounding Methods 0.000 claims description 2
- 229910021389 graphene Inorganic materials 0.000 claims description 2
- 239000003077 lignite Substances 0.000 claims description 2
- 229920001568 phenolic resin Polymers 0.000 claims description 2
- 239000005011 phenolic resin Substances 0.000 claims description 2
- 239000002904 solvent Substances 0.000 claims description 2
- 230000000977 initiatory effect Effects 0.000 claims 1
- 230000000379 polymerizing effect Effects 0.000 claims 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical class O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 abstract description 19
- 239000002245 particle Substances 0.000 abstract description 6
- 230000000052 comparative effect Effects 0.000 description 16
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- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 238000006116 polymerization reaction Methods 0.000 description 2
- 238000011085 pressure filtration Methods 0.000 description 2
- 238000001179 sorption measurement Methods 0.000 description 2
- 241001606224 Betula ermanii Species 0.000 description 1
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 description 1
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- 238000010539 anionic addition polymerization reaction Methods 0.000 description 1
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- PCHJSUWPFVWCPO-UHFFFAOYSA-N gold Chemical compound [Au] PCHJSUWPFVWCPO-UHFFFAOYSA-N 0.000 description 1
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Landscapes
- Solid-Sorbent Or Filter-Aiding Compositions (AREA)
Abstract
The invention discloses a preparation method of a high-temperature-resistant salt-resistant fluid loss additive, a high-temperature high-density saturated water-based drilling fluid and a preparation method thereof. The invention also provides a high-temperature high-density saturated brine drill containing the high-temperature-resistant and salt-resistant fluid loss agentWell fluid, and the saturated salt water drilling fluid is subjected to high temperature (220 ℃) and high density (2.4 g/cm) by changing the particle size grading relation of a drilling fluid system 3 ) And the drilling fluid shows good rheological property and water loss wall building property, and can meet the requirements of deep well drilling.
Description
Technical Field
The invention relates to the technical field of petroleum and natural gas, in particular to a high-temperature high-density saturated brine drilling fluid and a preparation method thereof.
Background
Currently, under the background of excessive development of shallow layer oil and gas resources, oil and gas exploration and development face triple pressure that oil and gas targets are complex, safety and environmental protection are strict, and oil and gas requirements are sharply increased. The depth of deep reservoirs in China generally exceeds 5000m, the bottom temperature is 180-260 ℃, and most regions have large salt-gypsum layers. At present, drilling of ultra-deep wells is carried out in oil fields such as Daqing, south China sea, sichuan, tarim, hongkong and the like. Therefore, the high-temperature-resistant high-density saturated saline drilling fluid system with excellent performance is a key factor for the successful drilling of deep saline-gypsum formations.
A large number of drilling practices show that the high-density saturated brine drilling liquid system has the problems of difficult rheological property regulation and control, large high-temperature and high-pressure filtration loss, solid-phase weighted material sedimentation and the like at high temperature. In a drilling site, the high-density saturated saline drilling fluid is easy to have vicious cycles of weighting thickening, treating viscosity reduction, weighting material sedimentation (causing downhole complexity and simultaneously reducing the density of the drilling fluid) and re-weighting, and the rheological property and the high-temperature sedimentation stability of the drilling fluid are difficult to be considered. In addition, high temperature degradation failure of the treating agent is one of the main causes of increased high temperature and high pressure fluid loss and rheological property changes of the drilling fluid. Therefore, with the advance of exploration of oil and gas resources to deep strata in China, a high-temperature high-density saturated saline drilling fluid system with excellent performance and outstanding high-temperature stability is developed, and the high-temperature high-density saturated saline drilling fluid system has extremely important significance for safe and efficient drilling of deep strata such as ultrahigh-temperature, high-density, salt-gypsum layers and high-pressure saline layers.
Disclosure of Invention
The invention aims to provide a high-temperature-resistant salt-resistant fluid loss additive, a preparation method thereof and a high-temperature high-density saturated salt water drilling fluid which has the characteristics of strong temperature resistance, good rheological property at high density, strong salt pollution resistance and the like.
The technical scheme of the invention is as follows:
in a first aspect, the invention provides a high temperature resistant and salt resistant fluid loss additive, which is copolymerized from a monomer composition containing 2-acrylamido-2-methylpropanesulfonic acid, sodium p-styrenesulfonate, N-vinylpyrrolidone and dimethyldiallylammonium chloride.
In the monomer composition, the molar ratio of 2-acrylamide-2-methyl propane sulfonic acid to sodium p-styrene sulfonate to N-vinyl pyrrolidone to dimethyl diallyl ammonium chloride is 1 (0.5-5) to (1-4).
In a preferable case, in order to further improve the thermal stability and the salt resistance of the high-temperature resistant fluid loss additive, the molar ratio of the 2-acrylamido-2-methylpropanesulfonic acid to the sodium p-styrenesulfonate to the N-vinylpyrrolidone to the dimethyldiallylammonium chloride is 1 (2-3.5) to (1.5-3).
The high-temperature-resistant and salt-resistant fluid loss additive basically comprises the following molecular structures: (1) by introducing anionic polymerization reaction monomers of 2-acrylamide-2-methylpropanesulfonic acid and sodium p-styrenesulfonate with excellent temperature resistance and salt calcium resistance, the temperature resistance and salt tolerance of the polymer are enhanced; (2) introducing a nonionic N-vinyl pyrrolidone monomer, wherein the side chain of the monomer often has a lactam group strong adsorbability group and a certain polarity, so that the monomer is easily adsorbed by clay particles to form a certain solvation film, thereby obtaining a stable colloid and maintaining the comprehensive performance of the drilling fluid; (3) the dimethyl diallyl ammonium chloride with cationic groups is introduced, so that the rigidity of polymer molecular chains is improved, the adsorption capacity of the polymer on clay particles is enhanced, and the filtrate loss reduction performance of the drilling fluid is improved.
In a second aspect, the invention provides a preparation method of the high-temperature-resistant fluid loss additive, which comprises the following steps: in the presence of water as solvent and initiator, 2-acrylamide-2-methyl propane sulfonic acid, sodium p-styrene sulfonate, N-vinyl pyrrolidone and dimethyl diallyl ammonium chloride are polymerized.
In the method, the molar ratio of the dosage of the 2-acrylamide-2-methyl propane sulfonic acid to the dosage of the sodium p-styrene sulfonate to the dosage of the N-vinyl pyrrolidone to the dosage of the dimethyl diallyl ammonium chloride can be 1 (0.5-5) to (1-4), and preferably 1 (2-4) to (1.5-3).
In the method, the preferable initiator is a mixture of sodium bisulfite and ammonium persulfate, the molar ratio of the two is 1.
In the method of the present invention, the polymerization conditions may include: the pH is 6.0-8.0, the temperature is 40-60 deg.C, and the time is 4-8h. In order to further improve the heat stability and salt resistance of the high temperature resistant fluid loss additive, preferably, the polymerization conditions include: the pH was 7, the temperature was 55 ℃ and the time was 6h.
In the present invention, N-vinylpyrrolidone, dimethyldiallylammonium chloride, sodium p-styrenesulfonate, 2-acrylamido-2-methylpropanesulfonic acid are commercially available from Yuehua Chemicals Co., ltd;
sodium bisulfite and ammonium persulfate are available from Woodwarfing Chemicals, inc.
The preparation steps of the high-temperature-resistant salt-resistant fluid loss additive are as follows:
s1, dissolving 2-acrylamide-2-methylpropanesulfonic acid in deionized water, and adjusting the pH to 7 by using a sodium hydroxide solution;
s2, sequentially adding sodium p-styrenesulfonate, N-vinyl pyrrolidone and dimethyl diallyl ammonium chloride according to the proportion of the dosage molar ratio of 2-acrylamide-2-methylpropanesulfonic acid to sodium p-styrenesulfonate, N-vinyl pyrrolidone to dimethyl diallyl ammonium chloride of 1 (2-3.5) to (1.5-3), and stirring for 20-40min;
s3, under the protection of nitrogen, heating the monomer reaction solution to 55 ℃, reacting for 20-40min, adding a mixture of sodium bisulfite and ammonium persulfate, and reacting for 6h to obtain a glue liquid product;
and S4, repeatedly purifying the product obtained in the step S3 by using absolute ethyl alcohol and acetone, drying the product for 12 hours by using an oven at the temperature of 100 ℃, and crushing the product to obtain the high-temperature-resistant fluid loss agent for the drilling fluid.
In a third aspect, the invention provides a high-temperature high-density saturated salt water drilling fluid, which comprises 100 parts by weight of clear water, 3-5 parts by weight of bentonite, 0.1-0.2 part by weight of sodium carbonate, 0.5-1.5 parts by weight of the high-temperature-resistant salt-resistant filtrate reducer, 3-5 parts by weight of viscosity reducer, 1-2 parts by weight of nano plugging agent, 0.5-1 part by weight of high-temperature protective agent, 0.5-0.8 part by weight of sodium hydroxide, 30 parts by weight of sodium chloride and barite which is suitable for weighting to required density; wherein,
preferably, the high-temperature-resistant and salt-resistant filtrate reducer is prepared by the preparation steps.
Preferably, the filtrate reducer is a coupling phenolic resin which is purchased from Sichuan Zhengrong industries, inc. and has the brand number ZR-13.
Preferably, the viscosity reducer is sulfonated lignite, which is purchased from Kyowa chemical engineering, LLC under the brand name of SMC.
Preferably, the nano plugging agent is graphene, is purchased from petroleum science and technology ltd of bullion, southwestern Sichuan, and has the brand number of SMXFT.
Preferably, the high-temperature protective agent is sodium polyacrylate which is purchased from Chengdu Xixia chemical reagent limited company and is of a brand of sodium polyacrylate.
Preferably, the barite is a mixture of API barite and ultramicro barite, and the compounding weight ratio of the API barite: ultra-micro barite =8:2; the API barite is purchased from Sichuan Haiwo oil engineering technology Co., ltd, and the brand is API barite; the ultra-micro barite is purchased from a processing plant of the mineral products of the weaving gold of the Nanowan industry Co., ltd and is marked as SE10E.
Preferably, the bentonite is purchased from Bentonite GmbH, nonrezhijie, xinjiang.
The sodium carbonate, sodium hydroxide and sodium chloride were purchased from a metropolitan dragon chemical reagent plant.
The preparation method of the high-temperature-resistant high-density saturated brine drilling fluid comprises the following preparation steps:
s1, adding bentonite and sodium carbonate into clear water while stirring at a rotating speed of 12000r/min, stirring for 30min, and then maintaining for 24h at 25 ℃;
s2, adding a high-temperature-resistant fluid loss additive, and stirring at a rotating speed of 12000r/min for 40min;
s3, sequentially adding a filtrate reducer, a viscosity reducer, a nano plugging agent, a high-temperature protective agent, sodium hydroxide and sodium chloride, and stirring at the rotating speed of 12000r/min for 60min;
s4, finally, according to the weight ratio of API barite: the ultrafine barite is 8:2, and adjusting the density of the drilling fluid to 2.4g/cm 3 And stirring for 60min at the rotating speed of 12000r/min to prepare the high-temperature-resistant high-density saturated salt water drilling fluid.
Has the beneficial effects that:
compared with the prior art, the high-temperature-resistant high-density saturated brine drilling fluid has the beneficial effects that:
(1) By utilizing the principle of greatly improving the clay surface adsorption capacity of the filtrate reducer in the drilling fluid under the high-temperature condition, the molecular design of the filtrate reducer is carried out, and a novel filtrate reducer with the temperature resistance of 220 ℃ and the salt (saturation) resistance is developed;
(2) Based on the moderate crosslinking function of the treating agents at high temperature, the high-temperature degradation of the treating agents is counteracted or partially counteracted, so that the problem that the dosage of the treating agents is inevitably and greatly increased when the temperature is increased is solved, the performance of the drilling fluid at high temperature is improved, and the consumption and dosage of the treating agents are reduced;
(3) By introducing the ultrafine barite and adjusting the grain size grading of the barite, the drilling fluid system has a wider grain size distribution range, which is beneficial to forming multistage effective filling of weighted particles, realizing compact particle packing to improve the quality of filter cakes, and exerting 'bearing drag reduction' of smaller particles to improve the rheological property, and finally realizing effective improvement of the comprehensive performance of the high-density drilling fluid;
(4) The novel high-temperature-resistant 220 ℃ high-density saturated brine drilling fluid system is successfully established, has the characteristics of strong temperature resistance, low viscosity, easy control, low high-temperature and high-pressure water loss and the like, can meet the drilling requirements of deep wells and ultra-deep wells, provides reference and basis for promoting the technical development of the high-temperature and high-density water-based drilling fluid of deep wells in China, and has good popularization and application prospects.
Detailed Description
In order to make the objects, technical solutions and advantages of the present invention more apparent, the present invention is further described in detail with reference to the following embodiments. It should be understood that the specific embodiments described herein are merely illustrative of the invention and do not limit the invention.
Preparation example 1:
s1, dissolving 10g of 2-acrylamido-2-methylpropanesulfonic acid in 150g of deionized water, and adjusting the pH value to 7 by using a sodium hydroxide solution;
s2, sequentially adding sodium p-styrenesulfonate, N-vinylpyrrolidone and dimethyldiallylammonium chloride according to the proportion of the 2-acrylamido-2-methylpropanesulfonic acid to the sodium p-styrenesulfonate, the N-vinylpyrrolidone and the dimethyldiallylammonium chloride to the mixture according to the molar ratio of 1;
s3, under the protection of nitrogen, heating the monomer reaction solution to 55 ℃, reacting for 30min, then adding 0.3g of a mixture of sodium bisulfite and ammonium persulfate, and reacting for 6h to obtain a glue solution-like product;
and S4, repeatedly purifying the product obtained in the step S3 by using absolute ethyl alcohol and acetone, drying the product for 12 hours in an oven at the temperature of 100 ℃, and crushing the product to obtain the high-temperature-resistant and salt-resistant filtrate reducer A1 for the drilling fluid.
Preparation example 2:
s1, dissolving 5g of 2-acrylamido-2-methylpropanesulfonic acid in 150g of deionized water, and adjusting the pH value to 6 by using a sodium hydroxide solution;
s2, sequentially adding sodium p-styrenesulfonate, N-vinylpyrrolidone and dimethyldiallylammonium chloride according to the molar ratio of the 2-acrylamido-2-methylpropanesulfonic acid to the sodium p-styrenesulfonate to the N-vinylpyrrolidone to the dimethyldiallylammonium chloride being 1.5;
s3, under the protection of nitrogen, heating the monomer reaction solution to 40 ℃, reacting for 20min, adding 0.15g of a mixture of sodium bisulfite and ammonium persulfate, and reacting for 4h to obtain a glue solution-like product;
and S4, repeatedly purifying the product obtained in the step S3 by using absolute ethyl alcohol and acetone, drying the product for 12 hours in an oven at the temperature of 100 ℃, and crushing the product to obtain the high-temperature-resistant and salt-resistant filtrate reducer A2 for the drilling fluid.
Preparation example 3:
s1, dissolving 15g of 2-acrylamido-2-methylpropanesulfonic acid in 150g of deionized water, and adjusting the pH value to 8 by using a sodium hydroxide solution;
s2, sequentially adding sodium p-styrenesulfonate, N-vinylpyrrolidone and dimethyldiallylammonium chloride according to the proportion of the dosage molar ratio of 2-acrylamido-2-methylpropanesulfonic acid to sodium p-styrenesulfonate, N-vinylpyrrolidone to dimethyldiallylammonium chloride being 1;
s3, under the protection of nitrogen, heating the monomer reaction solution to 60 ℃, reacting for 40min, then adding 0.8g of a mixture of sodium bisulfite and ammonium persulfate, and reacting for 8h to obtain a glue solution-like product;
and S4, repeatedly purifying the product obtained in the step S3 by using absolute ethyl alcohol and acetone, drying the product for 12 hours by using an oven at the temperature of 100 ℃, and crushing the product to obtain the high-temperature-resistant salt-resistant filtrate reducer A3 for the drilling fluid.
Comparative preparation example 1:
a high-temperature-resistant and salt-resistant fluid loss additive DA1 was prepared according to the method of preparation example 1, except that 2-acrylamido-2-methylpropanesulfonic acid was not added.
Comparative preparation example 2
The high-temperature-resistant salt-resistant fluid loss additive DA2 was prepared according to the method of preparation example 1 except that sodium p-styrenesulfonate was not added.
Comparative preparation example 3
The high temperature resistant and salt resistant filtrate reducer was prepared according to the method of preparation example 1 except that no N-vinyl pyrrolidone was added to prepare the high temperature resistant and salt resistant filtrate reducer DA3.
Comparative preparation example 4
The high temperature resistant salt-resistant fluid loss additive DA4 was prepared according to the method of preparation example 1, except that dimethyldiallylammonium chloride was not added.
Example 1:
a preparation method of a high-temperature-resistant high-density saturated brine drilling fluid F1 comprises the following preparation steps:
s1, adding 4 parts by weight of bentonite and 0.15 part by weight of sodium carbonate into 100 parts by weight of clear water under stirring at a rotating speed of 12000r/min, stirring for 30min, and then maintaining for 24h at 25 ℃;
s2, adding 1 part by weight of high-temperature-resistant and salt-resistant filtrate reducer A1 into the filtrate reducer, and stirring the mixture for 40min at the rotating speed of 12000 r/min;
s3, sequentially adding 4 parts by weight of fluid loss additive, 4 parts by weight of viscosity reducer, 1.5 parts by weight of nano plugging agent, 0.8 part by weight of high-temperature protective agent, 0.6 part by weight of sodium hydroxide and 30 parts by weight of sodium chloride, and stirring at the rotating speed of 12000r/min for 60min;
s4, finally, according to the weight ratio of API barite: the ultrafine barite is 8:2, and adjusting the density of the drilling fluid to 2.4g/cm 3 And stirring for 60min at the rotating speed of 12000r/min to prepare the high-temperature-resistant high-density saturated salt water drilling fluid F2.
Example 2
A preparation method of a high-temperature-resistant high-density saturated brine drilling fluid F2 comprises the following preparation steps:
s1, adding 3 parts by weight of bentonite and 0.1 part by weight of sodium carbonate into 100 parts by weight of clear water under stirring at a rotating speed of 12000r/min, stirring for 30min, and then maintaining for 24h at 25 ℃;
s2, adding 0.5 part by weight of high-temperature-resistant and salt-resistant filtrate reducer A2 into the filtrate reducer, and stirring the mixture for 40min at the rotating speed of 12000 r/min;
s3, sequentially adding 3 parts by weight of fluid loss additive, 3 parts by weight of viscosity reducer, 1 part by weight of nano plugging agent, 0.5 part by weight of high-temperature protective agent, 0.5 part by weight of sodium hydroxide and 30 parts by weight of sodium chloride, and stirring at the rotating speed of 12000r/min for 60min;
s4, finally, according to the weight ratio of API barite: the ultrafine barite is 8:2, and adjusting the density of the drilling fluid to 2.4g/cm 3 And stirring for 60min at the rotating speed of 12000r/min to prepare the high-temperature-resistant high-density saturated salt water drilling fluid F2.
Example 3
A preparation method of a high-temperature-resistant high-density saturated brine drilling fluid F3 comprises the following preparation steps:
s1, adding 5 parts by weight of bentonite and 0.2 part by weight of sodium carbonate into 100 parts by weight of clear water under stirring at a rotating speed of 12000r/min, stirring for 30min, and then maintaining for 24h at 25 ℃;
s2, adding 1.5 parts by weight of high-temperature-resistant salt-resistant fluid loss additive A3 into the filtrate, and stirring the mixture for 40min at the rotating speed of 12000 r/min;
s3, adding 5 parts by weight of fluid loss additive, 5 parts by weight of viscosity reducer, 2 parts by weight of nano plugging agent, 1 part by weight of high-temperature protective agent, 0.8 part by weight of sodium hydroxide and 30 parts by weight of sodium chloride in sequence, and stirring at the rotating speed of 12000r/min for 60min;
s4, finally, according to the weight ratio of API barite: the ultrafine barite is 8:2, and adjusting the density of the drilling fluid to 2.4g/cm 3 And stirring for 60min at the rotating speed of 12000r/min to prepare the high-temperature-resistant high-density saturated salt water drilling fluid F3.
Comparative example 1
The method of example 1 was followed except that the high temperature resistant high density saturated brine drilling fluid was not added with the high temperature resistant salt loss additive A1, i.e. the water-based drilling fluid DFl was formulated as follows: 100 parts by weight of clear water, 4 parts by weight of bentonite, 0.15 part by weight of sodium carbonate, 4 parts by weight of filtrate reducer, 4 parts by weight of viscosity reducer, 1.5 parts by weight of nano plugging agent, 0.8 part by weight of high-temperature protective agent, 0.6 part by weight of sodium hydroxide, 30 parts by weight of sodium chloride and barite which is suitable for weighting to the required density.
Comparative example 2
A high temperature resistant high density saturated brine drilling fluid was prepared as in example 1 except that the high temperature resistant salt tolerant fluid loss additive used was DA1 and a water-based drilling fluid DF2 was prepared.
Comparative example 3
A high temperature resistant high density saturated brine drilling fluid was prepared as in example 1 except that the high temperature resistant salt tolerant fluid loss additive used was DA2 to make a water-based drilling fluid DF3.
Comparative example 4
A high temperature resistant high density saturated brine drilling fluid was prepared as in example 1 except that the high temperature resistant salt tolerant filtrate loss reducer used was DA3 to produce water-based drilling fluid DF4.
Comparative example 5
A high temperature resistant high density saturated brine drilling fluid was prepared as in example 1 except that the high temperature resistant salt tolerant filtrate loss reducer used was DA4 to produce a water-based drilling fluid DF5.
Comparative example 6
A high temperature resistant high density saturated brine drilling fluid was prepared as in example 1 except that the barite used was API barite to produce water-based drilling fluid DF6.
Comparative example 7
A high temperature resistant high density saturated brine drilling fluid was prepared as in example 1 except that the barite used was ultra-micro barite to produce water-based drilling fluid DF7.
Test example 1
Referring to GB/T16783.1-2014 oil and gas industry drilling fluid field test first part: water-based drilling fluid, the high temperature resistant high density saturated brine drilling fluids prepared in examples 1 to 3 and comparative examples 1 to 7 were evaluated.
TABLE 1 high temperature resistant high density saturated brine drilling fluid performance test results
From the test results in table 1, it can be seen that the high temperature and high density resistant saturated brine drilling fluids prepared in examples 1 to 3 have good rheological properties and water loss wall building properties, and after aging at 220 ℃, the rheological properties change slightly, and the high temperature and high pressure filtration loss is also controlled below 15 mL; the formula of the drilling fluid of the comparative example 1 is not added with the high-temperature-resistant salt-resistant fluid loss additive, so that the temperature resistance and salt resistance of the drilling fluid system are reduced, the rheological property of the drilling fluid system prepared in the comparative example 1 is obviously deteriorated after the drilling fluid system is aged at 220 ℃, and the high-temperature high-pressure fluid loss is increased; the high-temperature-resistant and salt-resistant filtrate reducer added in the formula of the drilling fluid of the comparative examples 2 to 5 is not prepared according to experimental design, so that the comprehensive performance of the drilling fluid is reduced compared with that of the drilling fluid of the examples 1 to 3; the weighting agents added in the formulas of the drilling fluids of the comparative examples 6 to 7 are API barite and ultramicro barite respectively, the viscosity of the drilling fluid is increased, the filtration loss is increased, wherein a drilling fluid system adopting the ultramicro barite for weighting contains a large amount of micro particles, and the rheological property and the water loss wall building property are out of control.
Claims (7)
1. The high temperature resistant and salt resistant filtrate reducer is characterized by being prepared by polymerizing and copolymerizing 2-acrylamido-2-methylpropanesulfonic acid, sodium p-styrenesulfonate, N-vinyl pyrrolidone and dimethyl diallyl ammonium chloride under the initiation of an initiator, wherein the molar ratio of the 2-acrylamido-2-methylpropanesulfonic acid to the sodium p-styrenesulfonate to the N-vinyl pyrrolidone to the dimethyl diallyl ammonium chloride is 1 (2-3.5) to 1.5-3.
2. The method for preparing the high-temperature-resistant fluid loss additive according to claim 1, which comprises the following steps: in the presence of water as solvent and initiator, 2-acrylamide-2-methyl propane sulfonic acid, sodium p-styrene sulfonate, N-vinyl pyrrolidone and dimethyl diallyl ammonium chloride are polymerized.
3. The process according to claim 2, characterized in that the preferred initiator is a mixture of sodium bisulfite, ammonium persulfate in a molar ratio of 1 to 1, and the amount of agent is 0.1 to 1%, preferably 0.6%, of the total weight of 2-acrylamido-2-methylpropanesulfonic acid, sodium p-styrenesulfonate, N-vinylpyrrolidone and dimethyldiallylammonium chloride.
4. The method according to claims 1 to 3, wherein the preparation steps of the high temperature resistant and salt resistant fluid loss additive are as follows:
s1, dissolving 2-acrylamide-2-methylpropanesulfonic acid in deionized water, and adjusting the pH to 6.0-8.0 by using a sodium hydroxide solution;
s2, sequentially adding sodium p-styrenesulfonate, N-vinylpyrrolidone and dimethyl diallyl ammonium chloride according to the molar ratio of the dosage of 2-acrylamide-2-methylpropanesulfonic acid to the dosage of sodium p-styrenesulfonate, N-vinylpyrrolidone and dimethyl diallyl ammonium chloride being 1 (2-3.5) to (1.5-3) and stirring for 20-40min;
s3, under the protection of nitrogen, heating the monomer reaction solution to 40-60 ℃, reacting for 20-40min, adding a mixture of sodium bisulfite and ammonium persulfate, and reacting for 4-6 h to obtain a glue solution-shaped product;
and S4, repeatedly purifying the product obtained in the step S3 by using absolute ethyl alcohol and acetone, drying the product for 12 hours in an oven at the temperature of 100 ℃, and crushing the product to obtain the high-temperature resistant filtrate reducer for the drilling fluid.
5. The high-temperature-resistant high-density saturated salt water drilling fluid is characterized by comprising, by weight, 100 parts of clear water, 3-5 parts of bentonite, 0.1-0.2 part of sodium carbonate, 0.5-1.5 parts of the high-temperature-resistant salt-resistant fluid loss additive according to claim 1, 3-5 parts of a fluid loss additive, 3-5 parts of a viscosity reducer, 1-2 parts of a nano plugging agent, 0.5-1 part of a high-temperature protective agent, 0.5-0.8 part of sodium hydroxide, 30 parts of sodium chloride and barite which is suitable for weighting to a required density.
6. The water-based drilling fluid according to claim 5, wherein the fluid loss additive is preferably a coupled phenolic resin, and the viscosity reducer is preferably sulfonated lignite; preferably, the nano plugging agent is graphene; preferably, the high-temperature protective agent is sodium polyacrylate; preferably, the barite is a mixture of API barite and ultramicro barite, and the compounding weight ratio is that API barite: ultramicro barite =8:2.
7. the preparation method of the high-temperature-resistant salt-resistant saturated water-based drilling fluid as claimed in claim 5, wherein the preparation method comprises the following steps:
s1, adding bentonite and sodium carbonate into clear water while stirring at a rotating speed of 12000r/min, stirring for 30min, and then maintaining for 24h at 25 ℃;
s2, adding a high-temperature-resistant salt-resistant fluid loss additive, and stirring at a rotating speed of 12000r/min for 40min;
s3, sequentially adding a fluid loss additive, a viscosity reducer, a nano plugging agent, a high-temperature protective agent, sodium hydroxide and sodium chloride, and stirring at a rotating speed of 12000r/min for 60min;
s4, finally, according to the weight ratio of API barite: the ultrafine barite is 8:2, and adjusting the density of the drilling fluid to 2.4g/cm 3 And stirring for 60min at the rotating speed of 12000r/min to prepare the high-temperature-resistant high-density saturated salt water drilling fluid.
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| CN118685155A (en) * | 2024-08-29 | 2024-09-24 | 东营市鑫林石油科技有限公司 | Temperature-resistant salt-resistant filtrate reducer for drilling fluid, and preparation method and application method thereof |
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| CN116589991A (en) * | 2023-07-11 | 2023-08-15 | 西南石油大学 | Salt recrystallization inhibitor for high-density brine completion fluid system and preparation method thereof |
| CN116589991B (en) * | 2023-07-11 | 2023-09-15 | 西南石油大学 | Salt recrystallization inhibitor for high-density brine completion fluid system and preparation method thereof |
| CN117624457A (en) * | 2024-01-24 | 2024-03-01 | 西南石油大学 | High-temperature-resistant high-salt calcium filtrate reducer and preparation method and application thereof |
| CN118685155A (en) * | 2024-08-29 | 2024-09-24 | 东营市鑫林石油科技有限公司 | Temperature-resistant salt-resistant filtrate reducer for drilling fluid, and preparation method and application method thereof |
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