CN116478670B - Water-based drilling fluid system and preparation method thereof - Google Patents
Water-based drilling fluid system and preparation method thereof Download PDFInfo
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- CN116478670B CN116478670B CN202310271365.7A CN202310271365A CN116478670B CN 116478670 B CN116478670 B CN 116478670B CN 202310271365 A CN202310271365 A CN 202310271365A CN 116478670 B CN116478670 B CN 116478670B
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- 238000005553 drilling Methods 0.000 title claims abstract description 136
- 239000012530 fluid Substances 0.000 title claims abstract description 118
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 111
- 229910001868 water Inorganic materials 0.000 title claims abstract description 111
- 238000002360 preparation method Methods 0.000 title abstract description 10
- 239000000706 filtrate Substances 0.000 claims abstract description 25
- 239000003638 chemical reducing agent Substances 0.000 claims abstract description 23
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical compound [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 claims abstract description 22
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 claims abstract description 22
- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 claims abstract description 16
- 239000001110 calcium chloride Substances 0.000 claims abstract description 16
- 229910001628 calcium chloride Inorganic materials 0.000 claims abstract description 16
- 239000011248 coating agent Substances 0.000 claims abstract description 16
- 239000000314 lubricant Substances 0.000 claims abstract description 12
- 239000001103 potassium chloride Substances 0.000 claims abstract description 11
- 235000011164 potassium chloride Nutrition 0.000 claims abstract description 11
- 239000011780 sodium chloride Substances 0.000 claims abstract description 11
- 239000001913 cellulose Substances 0.000 claims abstract description 9
- 229920002678 cellulose Polymers 0.000 claims abstract description 9
- 239000000654 additive Substances 0.000 claims description 39
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 claims description 30
- 239000002002 slurry Substances 0.000 claims description 30
- 230000000996 additive effect Effects 0.000 claims description 27
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims description 26
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical compound [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 claims description 20
- 239000003795 chemical substances by application Substances 0.000 claims description 14
- 229920000728 polyester Polymers 0.000 claims description 14
- VTYYLEPIZMXCLO-UHFFFAOYSA-L Calcium carbonate Chemical compound [Ca+2].[O-]C([O-])=O VTYYLEPIZMXCLO-UHFFFAOYSA-L 0.000 claims description 12
- TZCXTZWJZNENPQ-UHFFFAOYSA-L barium sulfate Chemical compound [Ba+2].[O-]S([O-])(=O)=O TZCXTZWJZNENPQ-UHFFFAOYSA-L 0.000 claims description 12
- 239000010428 baryte Substances 0.000 claims description 12
- 229910052601 baryte Inorganic materials 0.000 claims description 12
- 238000000034 method Methods 0.000 claims description 12
- 239000005543 nano-size silicon particle Substances 0.000 claims description 12
- 235000012239 silicon dioxide Nutrition 0.000 claims description 12
- 238000002156 mixing Methods 0.000 claims description 10
- 229910000029 sodium carbonate Inorganic materials 0.000 claims description 10
- 235000011121 sodium hydroxide Nutrition 0.000 claims description 10
- 238000007789 sealing Methods 0.000 claims description 9
- 229910000019 calcium carbonate Inorganic materials 0.000 claims description 6
- 238000001723 curing Methods 0.000 claims description 4
- 239000002245 particle Substances 0.000 claims description 2
- 230000000694 effects Effects 0.000 abstract description 12
- 229920000642 polymer Polymers 0.000 abstract description 12
- KXGFMDJXCMQABM-UHFFFAOYSA-N 2-methoxy-6-methylphenol Chemical class [CH]OC1=CC=CC([CH])=C1O KXGFMDJXCMQABM-UHFFFAOYSA-N 0.000 abstract description 10
- 239000004927 clay Substances 0.000 abstract description 10
- 229920001577 copolymer Polymers 0.000 abstract description 10
- BHPQYMZQTOCNFJ-UHFFFAOYSA-N Calcium cation Chemical compound [Ca+2] BHPQYMZQTOCNFJ-UHFFFAOYSA-N 0.000 abstract description 9
- 229910001424 calcium ion Inorganic materials 0.000 abstract description 9
- 238000005520 cutting process Methods 0.000 abstract description 9
- 229910001414 potassium ion Inorganic materials 0.000 abstract description 8
- 230000005764 inhibitory process Effects 0.000 abstract description 6
- 230000001965 increasing effect Effects 0.000 abstract description 5
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 abstract description 4
- 239000011575 calcium Substances 0.000 abstract description 4
- 229910052791 calcium Inorganic materials 0.000 abstract description 4
- 239000000084 colloidal system Substances 0.000 abstract description 2
- 238000013329 compounding Methods 0.000 abstract description 2
- 230000002708 enhancing effect Effects 0.000 abstract description 2
- 229910017053 inorganic salt Inorganic materials 0.000 abstract description 2
- 238000005461 lubrication Methods 0.000 abstract description 2
- 229910001415 sodium ion Inorganic materials 0.000 abstract description 2
- 230000000052 comparative effect Effects 0.000 description 31
- 238000003756 stirring Methods 0.000 description 11
- 239000011435 rock Substances 0.000 description 10
- 235000017550 sodium carbonate Nutrition 0.000 description 9
- 239000002981 blocking agent Substances 0.000 description 8
- 238000006703 hydration reaction Methods 0.000 description 7
- 230000036571 hydration Effects 0.000 description 6
- 230000008569 process Effects 0.000 description 6
- 238000000576 coating method Methods 0.000 description 5
- 230000009286 beneficial effect Effects 0.000 description 4
- 230000000887 hydrating effect Effects 0.000 description 4
- 239000003112 inhibitor Substances 0.000 description 4
- 239000003921 oil Substances 0.000 description 4
- NPYPAHLBTDXSSS-UHFFFAOYSA-N Potassium ion Chemical compound [K+] NPYPAHLBTDXSSS-UHFFFAOYSA-N 0.000 description 3
- 230000032683 aging Effects 0.000 description 3
- 150000001412 amines Chemical class 0.000 description 3
- 238000004140 cleaning Methods 0.000 description 3
- 239000013078 crystal Substances 0.000 description 3
- 230000005484 gravity Effects 0.000 description 3
- 150000003863 ammonium salts Chemical class 0.000 description 2
- 239000002131 composite material Substances 0.000 description 2
- 238000010276 construction Methods 0.000 description 2
- 239000006185 dispersion Substances 0.000 description 2
- 239000012634 fragment Substances 0.000 description 2
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- 238000012423 maintenance Methods 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 238000005259 measurement Methods 0.000 description 2
- 229920003023 plastic Polymers 0.000 description 2
- 239000004033 plastic Substances 0.000 description 2
- 229920002239 polyacrylonitrile Polymers 0.000 description 2
- 229920000447 polyanionic polymer Polymers 0.000 description 2
- 239000000377 silicon dioxide Substances 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- 238000010998 test method Methods 0.000 description 2
- 238000012360 testing method Methods 0.000 description 2
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- 240000007049 Juglans regia Species 0.000 description 1
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- 241000009334 Singa Species 0.000 description 1
- 238000005299 abrasion Methods 0.000 description 1
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- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 239000001257 hydrogen Substances 0.000 description 1
- 229910052739 hydrogen Inorganic materials 0.000 description 1
- 125000002887 hydroxy group Chemical group [H]O* 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
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- 229910052751 metal Inorganic materials 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
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- 238000000465 moulding Methods 0.000 description 1
- 230000003204 osmotic effect Effects 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 239000003209 petroleum derivative Substances 0.000 description 1
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- 125000000542 sulfonic acid group Chemical group 0.000 description 1
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Classifications
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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
- C09K8/04—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
-
- 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
-
- 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
- C09K8/06—Clay-free compositions
- C09K8/12—Clay-free compositions containing synthetic organic macromolecular compounds or their precursors
-
- 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
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/5045—Compositions based on water or polar solvents containing inorganic compounds
-
- 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
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/5086—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds
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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
- C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
-
- 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
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/12—Swell inhibition, i.e. using additives to drilling or well treatment fluids for inhibiting clay or shale swelling or disintegrating
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
- Y02P20/00—Technologies relating to chemical industry
- Y02P20/141—Feedstock
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- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Dispersion Chemistry (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Inorganic Chemistry (AREA)
- Lubricants (AREA)
- Earth Drilling (AREA)
Abstract
The invention relates to a water-based drilling fluid system and a preparation method thereof, and belongs to the technical field of drilling fluids. According to the water-based drilling fluid system, excessive calcium ions, sodium ions and potassium ions are provided for the system through the compounding of the calcium chloride, the potassium chloride and the sodium chloride, so that the inhibition and collapse resistance of the water-based drilling fluid system are ensured, and the activity of water is reduced; the high temperature resistant calcium resistant sulfonated phenolic resin filtrate reducer, the polyanionic cellulose and the sulfonate copolymer filtrate reducer together form the filtrate reducer of the drilling fluid, which can prevent the clay from being dehydrated under the condition of inorganic salt pollution, enhance the gel protection capability, and maintain the stability of the colloid of the drilling fluid by keeping and enhancing the binding water capability of the clay surface. The zwitterionic polymer strong coating agent plays a role in increasing sticking and cutting, and the lubricant plays a role in lubrication.
Description
Technical Field
The invention relates to a water-based drilling fluid system and a preparation method thereof, and belongs to the technical field of drilling fluids.
Background
In order to meet the technical requirements of modern drilling, a novel high-performance water-based drilling fluid is developed abroad in recent years, its performance approaches that of oil-based drilling fluids while being environmentally acceptable. The high-performance water-based drilling fluid mainly comprises shale inhibitor, coating agent, dispersing agent and filtrate reducer. In high-performance water-based drilling fluid, the amine inhibitor and the dispersion inhibitor PHPA act together to inhibit shale hydration dispersion. Firstly, low molecular weight amines penetrate the clay layer like potassium ions, binding the clay sheets together by electrostatic adsorption, hydrogen bonding, dipole action, etc., preventing water molecules from entering. Then, PHPA with high molecular weight is adsorbed on the surface of shale to play a role in covering and coating the shale. The integrity of the rock debris is maintained by the coating effect of the polymer, and the rock debris is prevented from being disintegrated in the flowing process. Therefore, by the synergistic effect of the chemical inhibition of amine and the coating and blocking of PHPA, the excellent inhibition effect can be achieved, and the total inhibition can be realized.
The mud shale in the areas of Wei Gang, double river, zhao Ao and the like of the Henan oilfield is easy to absorb water and expand, so that the well wall is unstable, and the complex conditions of drilling sticking, electrical measurement and the like are caused. The technical problems of well wall stability, well cleaning, reservoir protection and the like are solved in the well drilling, and the method becomes the key of the technical research of drilling fluid. However, the current water-based drilling fluid system cannot meet the requirements of well wall stability, well cleaning and reservoir protection in drilling due to insufficient inhibition.
Disclosure of Invention
The invention aims to provide a water-based drilling fluid system, which can solve the problem that the current water-based drilling fluid system cannot meet the requirements of well wall stability, well cleaning, reservoir protection and the like in drilling.
It is another object of the present invention to provide a method of preparing a water-based drilling fluid system.
In order to achieve the above purpose, the water-based drilling fluid system of the invention adopts the following technical scheme:
The water-based drilling fluid system mainly comprises base slurry and additives, wherein the additives mainly comprise the following components in parts by weight: 4-6 parts of calcium chloride, 5-8 parts of potassium chloride, 10-15 parts of sodium chloride, 0.1-0.2 part of a strong amphoteric ion polymer coating agent, 0.5-1.0 part of a sulfonated phenolic resin filtrate reducer, 0.5-1.0 part of polyanionic cellulose, 0.5-1.0 part of a sulfonate copolymer filtrate reducer and 2-4 parts of a lubricant.
According to the water-based drilling fluid system, excessive calcium ions, sodium ions and potassium ions are provided for the system through the compounding of the calcium chloride, the potassium chloride and the sodium chloride, so that the inhibition and collapse resistance of the water-based drilling fluid system are ensured, and the activity of water is reduced; the high temperature resistant calcium resistant sulfonated phenolic resin filtrate reducer, the polyanionic cellulose and the sulfonate copolymer filtrate reducer together form the filtrate reducer of the drilling fluid, which can prevent the clay from being dehydrated under the condition of inorganic salt pollution, enhance the gel protection capability, and maintain the stability of the colloid of the drilling fluid by keeping and enhancing the binding water capability of the clay surface. The zwitterionic polymer strong coating agent plays a role in increasing sticking and cutting, and the lubricant plays a role in lubrication.
According to the water-based drilling fluid system provided by the invention, calcium chloride in the additive is an inhibitor of the system, on one hand, calcium ions are adsorbed onto the surface of the crystal layer to neutralize negative charges of clay, so that negative repulsive force between crystal layers is weakened, mutual attraction between crystal layers is facilitated, and stability is improved; on the other hand, because calcium ions exist in the system, the calcium ions are not easy to exchange with calcium soil in the shale in the drilling process, so that the purpose of reducing hydration expansion of the shale is achieved; potassium chloride provides enough potassium ions, on one hand, the osmotic hydration effect is weakened through the concentration difference of the adsorbed ions on the clay surface, and on the other hand, the water molecules are prevented from entering through the effective mosaic of the potassium ions; the sodium chloride mainly reduces the activity of water, and achieves the effect of stabilizing the well wall to protect the oil-gas layer; the polymer treating agents such as high temperature resistant calcium resistant sulfonated phenolic resin filtrate reducer, polyanion cellulose and sulfonate copolymer filtrate reducer and the like can provide strong hydration groups such as sulfonic acid groups, hydroxyl groups, amino groups and the like adsorbed by clay, thereby being beneficial to keeping the clay with thick hydration film capability, preventing coalescence and de-hydration and solving the problem of increased filtrate loss caused by excessive calcium ions in the system. The lubricant can effectively reduce friction resistance between the drilling tool and the open hole well wall and between the drilling tool and the metal casing, and has the purposes of improving drilling speed, preventing drilling sticking and reducing abrasion of the drilling tool.
When the water-based drilling fluid system provided by the invention is used for Zhao Ao blocks of Henan oil fields, the result shows that the water-based drilling fluid system provided by the invention can effectively reduce the collapse pressure increment of complex shale stratum to 0.1, achieve the effect of being beneficial to the protection of hydrocarbon reservoirs and improve the average mechanical drilling rate by 40.1%; the average well diameter expansion rate is reduced by more than 52%, and the well cementation quality and high-quality rate are improved by 15.9%.
Preferably, the zwitterionic polymer strong coating is an FA367 coating.
Preferably, the sulfonated phenolic resin filtrate reducer is SMPFL-C filtrate reducer.
Preferably, the sulfonate copolymer fluid loss additive is a DSP-2 fluid loss additive.
In order to enable the drilling fluid to play a role in plugging complex stratum such as a low-pressure leakage layer and a high-permeability layer, preferably, the additive further comprises a plugging agent, wherein the plugging agent comprises the following components in parts by weight: 2-3 parts of nano polyester plugging agent, 2-3 parts of nano silicon dioxide plugging agent and 2-3 parts of superfine calcium carbonate.
Preferably, the nano polyester blocking agent is nano polyester NP-1. Preferably, the particle size of the nano silicon dioxide plugging agent is 1-100 nm. Preferably, the nano-silica blocking agent is nano-silica NS-1.
Preferably, the weight part of the lubricant is 2-3 parts. Preferably, the lubricant is white oil.
In order to adjust the specific gravity of the drilling fluid, the water-based drilling fluid system preferably further comprises barite.
The specific composition and components of the base slurry can be referred to the base slurry adopted in the existing water-based drilling fluid, and preferably, the base slurry comprises the following components in parts by weight: 0.1-0.2 part of caustic soda, 0.2-0.3 part of sodium carbonate and 100 parts of water. Soda ash and caustic soda can improve the slurry production rate of drilling fluid and have the function of adjusting pH.
Preferably, the base slurry is prepared by a process comprising the steps of: mixing water, caustic soda and sodium carbonate uniformly, sealing and hydrating.
Preferably, the time for hydration of the seal is not less than 24 hours.
The technical scheme adopted by the preparation method of the water-based drilling fluid system is as follows:
the preparation method of the water-based drilling fluid system comprises the following steps: adding the components of the additive into the base slurry according to the proportion, uniformly mixing, sealing and curing.
The preparation method of the water-based drilling fluid system provided by the invention has the advantages of simple preparation process, capability of being carried out on the existing production equipment and good field adaptability.
Preferably, when the water-based drilling fluid system further comprises barite, after mixing, adding the barite, mixing again, and then carrying out the seal maintenance.
In order to ensure the uniformity of the water-based drilling fluid system, the sealing maintenance time is preferably not less than 24 hours.
Detailed Description
The technical scheme of the invention is further described below with reference to specific embodiments.
The sulfonated phenolic resin filtrate reducer SMPFL-C used in examples 1-5 of the present invention was purchased from the institute of petroleum engineering, inc. of petrochemical industry Co., ltd; polyanionic cellulose PAC-LV was purchased from shandong angle oil adjuvant limited; zwitterionic polymer strong coating agent FA367 was purchased from the industrial company, of the middle-aged three-force, singa; the nano polyester plugging agent (nano polyester NP-1), the nano silicon dioxide plugging agent (nano silicon dioxide NS-1) and the sulfonate copolymer filtrate reducer DSP-2 are purchased from Shandong De cis source petroleum technology Co., ltd; calcium chloride, potassium chloride and sodium chloride were purchased from new east Yi Feng chemical materials Co., ltd; ultrafine calcium carbonate and barite are purchased from southward Utility company in southward; the lubricant was white oil No. 5, purchased from the martial arts golden chicken petroleum products company.
1. Specific examples of the water-based drilling fluid system of the present invention are as follows:
Example 1
The water-based drilling fluid system of the embodiment consists of base slurry, additives and barite; the base slurry consists of the following components in parts by weight: 0.1 part of caustic soda, 0.2 part of sodium carbonate and 100 parts of water; the additive consists of the following components in parts by weight: 4 parts of calcium chloride, 5 parts of potassium chloride, 10 parts of sodium chloride, 0.1 part of a zwitterionic polymer strong coating agent FA367, 0.5 part of a sulfonated phenolic resin filtrate reducer SMPFL-C, 0.5 part of polyanion cellulose, 20.5 parts of a sulfonate copolymer filtrate reducer DSP-20.5 parts, 2 parts of a lubricant, 2 parts of a nano polyester blocking agent (nano polyester NP-1), 2 parts of a nano silicon dioxide blocking agent (nano silicon dioxide NS-1) and 2 parts of superfine calcium carbonate; 16g of calcium chloride is taken as an additive which is correspondingly adopted in each 400mL of base slurry; the density of the water-based drilling fluid system of this example was 1.25g/cm 3.
The base slurry in the water-based drilling fluid system of this example was prepared by a process comprising the steps of: stirring caustic soda, sodium carbonate and water at high speed for 20min, mixing, and sealing and hydrating at room temperature for 24h.
Example 2
The water-based drilling fluid system of the embodiment consists of base slurry, additives and barite; the base slurry consists of the following components in parts by weight: 0.15 part of caustic soda, 0.25 part of sodium carbonate and 100 parts of water; the additive consists of the following components in parts by weight: 5 parts of calcium chloride, 6 parts of potassium chloride, 12.5 parts of sodium chloride, 0.15 part of a zwitterionic polymer strong coating agent FA367, SMPFL-C0.75 parts of a sulfonated phenolic resin filtrate reducer, 0.75 part of polyanionic cellulose, 0.75 part of a sulfonate copolymer filtrate reducer DSP-2, 2.5 parts of a lubricant, 2.5 parts of a nano polyester blocking agent (nano polyester NP-1), 2.5 parts of a nano silicon dioxide blocking agent (nano silicon dioxide NS-1) and 2.5 parts of superfine calcium carbonate; the amount of the additive adopted for each 400mL of the base slurry is 20g calculated by calcium chloride; the density of the water-based drilling fluid system of this example was 1.29g/cm 3.
The base slurry in the water-based drilling fluid system of this example was prepared by a process comprising the steps of: stirring caustic soda, sodium carbonate and water at high speed for 30min, mixing, and sealing and hydrating at room temperature for 24h.
Example 3
The water-based drilling fluid system of the embodiment consists of base slurry, additives and barite; the base slurry consists of the following components in parts by weight: 0.2 part of caustic soda, 0.3 part of sodium carbonate and 100 parts of water; the additive consists of the following components in parts by weight: 6 parts of calcium chloride, 8 parts of potassium chloride, 15 parts of sodium chloride, 0.2 part of a strong zwitterionic polymer coating agent FA367, SMPFL-C1 part of a sulfonated phenolic resin filtrate reducer, 1 part of polyanionic cellulose, 3 parts of a sulfonate copolymer filtrate reducer DSP-2 1 part, 3 parts of a lubricant, 3 parts of a nano polyester blocking agent (nano polyester NP-1), 3 parts of a nano silicon dioxide blocking agent (nano silicon dioxide NS-1) and 3 parts of superfine calcium carbonate; the amount of the additive adopted for each 400mL of the base slurry is 24g calculated by calcium chloride; the density of the water-based drilling fluid system of this example was 1.27g/cm 3.
The base slurry in the water-based drilling fluid system of this example was prepared by a process comprising the steps of: stirring caustic soda, sodium carbonate and water at high speed for 30min, mixing, and sealing and hydrating at room temperature for 24h.
Example 4
The water-based drilling fluid system of the embodiment consists of base slurry, additives and barite; the base slurry in this example was the same as that in example 2, and the additive was the same as that in example 3, with 20g of calcium chloride per 400mL of base slurry; the density of the water-based drilling fluid system of this example was 1.29g/cm 3.
Example 5
The water-based drilling fluid system of the embodiment consists of base slurry, additives and barite; the base slurry in this example was the same as that in example 3, and the additive was the same as that in example 2, with 24g of calcium chloride per 400mL of base slurry; the density of the water-based drilling fluid system of this example was 1.27g/cm 3.
Comparative example 1
The water-based drilling fluid system of this comparative example was different from the water-based drilling fluid system of example 1 only in that the weight part of calcium chloride in the additive in the water-based drilling fluid system of this comparative example was 3 parts.
Comparative example 2
The water-based drilling fluid system of this comparative example was different from the water-based drilling fluid system of example 3 only in that the weight part of calcium chloride in the additive in the water-based drilling fluid system of this comparative example was 7 parts.
Comparative example 3
The water-based drilling fluid system of this comparative example was different from the water-based drilling fluid system of example 1 only in that the weight part of potassium chloride in the additive in the water-based drilling fluid system of this comparative example was 4 parts.
Comparative example 4
The water-based drilling fluid system of this comparative example was different from the water-based drilling fluid system of example 3 only in that the weight part of potassium chloride in the additive in the water-based drilling fluid system of this comparative example was 9 parts.
Comparative example 5
The water-based drilling fluid system of this comparative example was different from the water-based drilling fluid system of example 1 only in that the weight part of sodium chloride in the additive in the water-based drilling fluid system of this comparative example was 8 parts.
Comparative example 6
The water-based drilling fluid system of this comparative example was different from the water-based drilling fluid system of example 3 only in that the weight part of sodium chloride in the additive in the water-based drilling fluid system of this comparative example was 17 parts.
Comparative example 7
The water-based drilling fluid system of this comparative example was different from the water-based drilling fluid system of example 1 only in that the zwitterionic polymer strong coating agent FA367 was replaced with the polymer coating agent BLZ-1 in the additives in the water-based drilling fluid system of this comparative example.
Comparative example 8
The water-based drilling fluid system of this comparative example differs from the water-based drilling fluid system of example 1 only in that the sulfonated phenolic resin fluid loss additive SMPFL-C was replaced with the hydrolyzed polyacrylonitrile ammonium salt fluid loss additive in the additives of the water-based drilling fluid system of this comparative example.
Comparative example 9
The water-based drilling fluid system of this comparative example differs from the water-based drilling fluid system of example 1 only in that the sulfonate copolymer fluid loss additive DSP-2 was replaced with a hydrolyzed polyacrylonitrile ammonium salt fluid loss additive in the additives of the water-based drilling fluid system of this comparative example.
The preparation method of the water-based drilling fluid system in any one of comparative examples 1-9 specifically comprises the following steps: adding the components in the additive in the water-based drilling fluid system into the base slurry according to the formula under the stirring condition, uniformly stirring, stirring at a high speed for 30min, sealing and curing for 24h, then adding barite according to the specific gravity of the drilling fluid, and uniformly mixing to obtain the composite drilling fluid.
2. Specific examples of the preparation method of the water-based drilling fluid system of the invention are as follows:
The method for preparing the water-based drilling fluid system in any one of the embodiments 1 to 5 specifically comprises the following steps: adding the components in the additive in the water-based drilling fluid system into the base slurry according to the formula under the stirring condition, uniformly stirring, stirring at a high speed for 30min, sealing and curing for 24h, then adding barite according to the specific gravity of the drilling fluid, and uniformly mixing to obtain the composite drilling fluid.
Experimental example 1
To evaluate the stability of the water-based drilling fluid systems of examples 1 to 5 and comparative examples 1 to 9, each water-based drilling fluid system was charged into an aging tank, rolled at 120℃for 16 hours, taken out, and cooled to room temperature. Each water-based drilling fluid system was then tested for density, plastic viscosity, dynamic shear force, medium pressure fluid loss, high temperature high pressure fluid loss, pH, calcium ion concentration, and potassium ion concentration before and after aging, and the test results are shown in tables 1-2. The density, the plastic viscosity, the dynamic shear force and the pH value are tested according to drilling fluid testing standards, the medium-pressure fluid loss is tested according to the specification in the standard SY/T6865-2012, the high-temperature high-pressure fluid loss is tested according to the specification in the standard SY/T7074-2016, and the calcium ion concentration and the potassium ion concentration are tested according to the specification in the standard GB/T601-2002.
TABLE 1 stability (Density, modeling viscosity, dynamic shear force, medium pressure fluid loss) of Water-based drilling fluid systems of examples 1-5, comparative examples 1-9
TABLE 2 stability of Water-based drilling fluid systems of examples 1-5, comparative examples 1-9 (high temperature high pressure fluid loss, pH, calcium ion concentration, and Potassium ion concentration)
As is clear from tables 1-2, the indexes such as the molding viscosity, the dynamic shear force, the fluid loss and the like of the drilling fluids of examples 1-5 did not change significantly before and after aging, indicating that the drilling fluids of examples 1-5 showed good temperature resistance.
Experimental example 2
Zhao 97 is one evaluation well deployed in the south of the capsule basin and sunk Zhao Ao-the nose-shaped structure of the greenhouse, and is designed to have a well depth of 2360m and constructed by a 40406 drilling crew. The biggest technical problem of the well is that the block walnut garden group shale develops, the water is easy to absorb and expand, the well wall is unstable, the complex conditions of drilling sticking, electrical measurement and the like are caused, the water-based drilling fluid system of the embodiment 1 is used from two places, the total length is 2160m, and the drilling density is reduced from 1.30g/cm 3 of the same block to 1.20g/cm 3; the average mechanical drilling speed is increased from 15.7m/h to 20.4m/h in the same block; the average well diameter expansion rate is reduced by more than 52%, and the well cementation quality and high-quality rate are improved by 15.9%. The field effect (drilling fluid performance) of the water-based drilling fluid system of example 1 is shown in Table 3. The test method of the initial cutting force and the final cutting force is as follows: injecting drilling fluid into a container, enabling a rotary drum to just invade a scale mark, stirring the drilling fluid at a high speed for 10s, standing for 10s, and measuring the maximum reading value when rotating at a rotating speed of 3r/min, namely, the initial cutting force (phi 3 Initially, the method comprises ) with the unit of Pa; stirring the drilling fluid at a high speed for 10s, standing for 10min, and measuring the maximum reading value when rotating at a rotating speed of 3r/min to obtain final cutting force (phi 3 Terminal (A) ) with the unit of Pa; the test method for water loss was carried out according to the method specified in standard GBT 16783-1997.
TABLE 3 field application Effect of the Water-based drilling fluid System of example 1
As can be seen from table 3, the water-based drilling fluid system of example 1 is used for the two-way construction of the Zhao 97 well, and can continuously maintain good rheological property during construction, the rheological stability has obvious advantages, and the good rheological property is beneficial to the separation efficiency of the solid control equipment and the flushing of the well wall; the solid phase pollution resistance is far superior to that of other commercially available water-based drilling fluids; the dynamic shear force is kept at 1.5-3.5 Pa, and the rock carrying capacity of the system is ensured.
From the analysis of the effects of low viscosity cutting, low density drilling completion and well diameter expansion rate reduction, the water-based drilling fluid system of the embodiment 1 is fully explained that a non-ideal semi-permeable membrane can be formed on the surface of rock, filtrate is slowed down to enter stratum, and the loss rate of rock strength is far lower than that of other drilling fluids in a zone; the drilling fluid density is reduced, the pressure difference at the bottom of the well is reduced, the pressure holding effect of rock fragments is reduced, the possibility of repeated crushing of the rock fragments is reduced, and the rock breaking efficiency of the drill bit is increased; the low viscosity cutting drilling fluid can enhance the impact force on the liquid flow at the bottom of the well, is easier to infiltrate into micro cracks formed when the drill bit impacts the rock at the bottom of the well, improves the drillability of the rock at the bottom of the well, and is more beneficial to improving the mechanical drilling rate; when in well cementation, the displacement efficiency and the well cementation quality can be effectively improved due to the well diameter rule and the low-viscosity cutting effect of the low-density agent of the drilling fluid.
Claims (7)
1. The water-based drilling fluid system is characterized by mainly comprising base slurry and additives, wherein the additives mainly comprise the following components in parts by weight: 4-6 parts of calcium chloride, 5-8 parts of potassium chloride, 10-15 parts of sodium chloride, 0.1-0.2 part of FA367 coating agent, 0.5-1.0 part of SMPFL-C filtrate reducer, 0.5-1.0 part of polyanionic cellulose, 0.5-1.0 part of DSP-2 filtrate reducer and 2-4 parts of lubricant.
2. The water-based drilling fluid system of claim 1, wherein the additive further comprises a plugging agent comprising the following components in parts by weight: 2-3 parts of nano polyester plugging agent, 2-3 parts of nano silicon dioxide plugging agent and 2-3 parts of superfine calcium carbonate.
3. The water-based drilling fluid system of claim 2, wherein the nano-polyester plugging agent is nano-polyester NP-1; the particle size of the nano silicon dioxide plugging agent is 1-100 nm.
4. The water-based drilling fluid system of claim 1, wherein the lubricant is present in an amount of 2 to 3 parts by weight.
5. The water-based drilling fluid system of claim 1, wherein the water-based drilling fluid system further comprises barite.
6. The water-based drilling fluid system of claim 1, wherein the base slurry is composed of the following components in parts by weight: 0.1-0.2 part of caustic soda, 0.2-0.3 part of sodium carbonate and 100 parts of water.
7. A method of preparing a water-based drilling fluid system according to any one of claims 1 to 6, comprising the steps of: adding the components of the additive into the base slurry according to the proportion, uniformly mixing, sealing and curing.
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