CN109233762B - Drilling fluid, preparation method and application - Google Patents
Drilling fluid, preparation method and application Download PDFInfo
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- CN109233762B CN109233762B CN201710555207.9A CN201710555207A CN109233762B CN 109233762 B CN109233762 B CN 109233762B CN 201710555207 A CN201710555207 A CN 201710555207A CN 109233762 B CN109233762 B CN 109233762B
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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
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- C—CHEMISTRY; METALLURGY
- C07—ORGANIC CHEMISTRY
- C07D—HETEROCYCLIC COMPOUNDS
- C07D233/00—Heterocyclic compounds containing 1,3-diazole or hydrogenated 1,3-diazole rings, not condensed with other rings
- C07D233/54—Heterocyclic compounds containing 1,3-diazole or hydrogenated 1,3-diazole rings, not condensed with other rings having two double bonds between ring members or between ring members and non-ring members
- C07D233/56—Heterocyclic compounds containing 1,3-diazole or hydrogenated 1,3-diazole rings, not condensed with other rings having two double bonds between ring members or between ring members and non-ring members with only hydrogen atoms or radicals containing only hydrogen and carbon atoms, attached to ring carbon atoms
- C07D233/61—Heterocyclic compounds containing 1,3-diazole or hydrogenated 1,3-diazole rings, not condensed with other rings having two double bonds between ring members or between ring members and non-ring members with only hydrogen atoms or radicals containing only hydrogen and carbon atoms, attached to ring carbon atoms with hydrocarbon radicals, substituted by nitrogen atoms not forming part of a nitro radical, attached to ring nitrogen atoms
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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
- 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
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Abstract
The invention discloses a drilling fluid, a preparation method and application. The drilling fluid comprises: the components are calculated according to the parts by weight, and 100 parts by weight of water is added; 0.5-5 parts by weight of a shale inhibitor; the shale inhibitor is 1-aminoethyl-3-methylimidazolium salt, and the structural formula of the shale inhibitor is as follows:
wherein R is Br and NO3、PF6Or BF4. The drilling fluid disclosed by the invention contains a shale inhibitor capable of effectively inhibiting hydration and dispersion of the shale, and can effectively prevent the surface hydration of montmorillonite in the shale when the drilling fluid is used for drilling a large-section shale stratum which is easy to cause borehole wall instability, so that the drilling fluid has the effects of reducing the expansion pressure of the shale and maintaining the stability of the borehole wall.
Description
Technical Field
The invention relates to the field of drilling, in particular to a drilling fluid, a preparation method and application.
Background
In the process of oil and gas drilling, the worldwide problem of instability of the wall of a shale stratum well is always puzzled by the technical personnel of petroleum engineering. Well collapse and hole shrinkage caused by instability of the well wall can not only cause downhole complexity such as well tripping and encountering resistance, drill jamming, torque increase, pump holding and the like, but also cause dropping of a drilling tool, deviation of the well track or scrapping of the whole well.
During drilling, 90% of borehole instability accidents occur in shale formations. The clay shale contains water-sensitive clay minerals such as montmorillonite, when the clay shale is contacted with the drilling fluid, free water in the drilling fluid invades pores and microcracks of the clay shale to cause hydration expansion of the clay, and the generated expansion pressure can reduce the strength of the clay shale, thereby causing instability of a well wall. Since oil does not cause clay swelling, oil-based drilling fluids have been the ideal choice for solving the problem of borehole wall shale instability over the past few decades. However, with the current tightening of environmental regulations, the use of oil-based drilling fluids is limited due to their severe environmental damage. Therefore, water-based drilling fluids with strong shale inhibition are becoming research hotspots.
The development of shale inhibitors as core treatment agents for highly inhibitory water-based drilling fluids has been the focus of research in the drilling fluid field. Most of the current opinion suggests that the main cause of shale borehole instability is clay hydration, including surface hydration and osmotic hydration. Researches show that the inhibitor capable of effectively inhibiting the hydration of the surface of the montmorillonite needs to have more than two amino groups, a hydrophobic framework, a relatively long molecular chain and the like, and mainly aims to enable inhibitor molecules to be embedded into an interlayer domain of the clay through cation exchange and tie up adjacent negatively charged clay crystal layers through the positively charged amino groups, and meanwhile, the hydrophobic molecular framework effectively inhibits the invasion of water molecules into the crystal layers. Shale inhibitors with the above molecular structures and properties have been widely studied and applied at home and abroad for the last decade. US 6,484,821B 1 describes a suppressive water-based drilling fluid for drilling mud shale formations. Which preferably comprises an aqueous-based continuous phase, a weighting agent and a compound of formula H2N-R-{OR'}x-Y, wherein R and R' are each alkylene groups having 1 to 6 carbon atoms, and x corresponds to a value of about 1 to about 25. The Y group should be an amine or alkoxy group, preferably a primary amine or methoxy group. WO 2008/031806A 1 describes C4-10Neutral or salt-like condensation products of dicarboxylic acids with alkanolamines, diamines or polyalkyleneamines are used as shale inhibitors. US 2007/0207932 a1 describes the use of 1, 2-cyclohexanediamines and salts thereof as drilling fluid shale inhibitors.
The shale inhibitors of the prior art have the following disadvantages:
(1) shale inhibitors of the prior art include small molecule inhibitors and high molecular polymer inhibitors. The small molecule inhibitor is mainly characterized in that nitrogen atoms with positive charges after protonation are inserted into a montmorillonite crystal layer, and adjacent negative montmorillonite crystal layers are bound through electrostatic attraction. However, most small molecule inhibitors such as glycidyltrimethylammonium chloride and dimethyldiallylammonium chloride have limited electrostatic binding due to the single protonatable nitrogen atom in the molecule. The imidazole nitrogen atom and the amino group in the 1-aminoethyl-3-methylimidazolium salt can be subjected to protonation reaction under a neutral environment to carry positive charges, so that the single molecule has high positive charge density, and a negative montmorillonite crystal layer can be better bound. And the hydrophobic five-membered ring structure can effectively prevent water molecules from invading into montmorillonite interlamination, thereby greatly inhibiting the surface hydration of montmorillonite and maintaining the stability of shale.
(2) The high molecular polymer inhibitor is easy to cause the bentonite in the drilling fluid to generate serious flocculation due to large molecular weight, and causes great negative effects on the rheological property and the filtration loss of the drilling fluid.
(3) Almost all current inhibitors are in solid powder form. When the solid powder is added into the drilling fluid, the drilling site constructor is easy to suck the powder and cause damage to the health of the constructor.
Disclosure of Invention
The invention provides a drilling fluid, a preparation method and application, and aims to solve the problem that a shale well wall is easy to destabilize in a drilling process in the prior art. The drilling fluid disclosed by the invention contains a shale inhibitor capable of effectively inhibiting hydration and dispersion of the shale, and can effectively prevent the surface hydration of montmorillonite in the shale when the drilling fluid is used for drilling a large-section shale stratum which is easy to cause borehole wall instability, so that the drilling fluid has the effects of reducing the expansion pressure of the shale and maintaining the stability of the borehole wall.
One of the purposes of the invention is to provide a drilling fluid.
The drilling fluid comprises:
the components are calculated according to the parts by weight,
100 parts by weight of water;
0.5-5 parts by weight of a shale inhibitor; preferably 1 to 3 parts by weight;
the shale inhibitor is 1-aminoethyl-3-methylimidazolium salt,
the structural formula is as follows:
wherein R is Br and NO3、PF6Or BF4Preferably Br and NO3(ii) a More preferably Br.
The clay shale contains water-sensitive clay minerals such as montmorillonite, when the clay shale is contacted with the drilling fluid, free water in the drilling fluid invades pores and microcracks of the clay shale to cause hydration expansion of the clay, and the generated expansion pressure can reduce the strength of the clay shale, so that borehole wall instability is easy to occur. The shale inhibitor provided by the invention is an amino-functionalized imidazole ionic liquid, imidazole nitrogen atoms and amino groups in the ionic liquid can be subjected to protonation reaction under a neutral environment to be positively charged, so that the positive charge density is high, a negatively-charged montmorillonite layer can be better bound, the amino-functionalized imidazole ionic liquid can be embedded into a montmorillonite interlayer through ion exchange, the protonated positively-charged imidazole nitrogen atoms and amino groups firmly bind an adjacent montmorillonite layer, and a hydrophobic five-membered ring structure can effectively prevent water molecules from invading into the montmorillonite interlayer, so that the surface hydration of the montmorillonite is greatly inhibited, and the stability of mud shale is maintained. And because the 1-aminoethyl-3-methylimidazolium salt is liquid at normal temperature and has extremely low vapor pressure, the health of drilling workers is not harmed.
In the present invention, the shale inhibitor may be a bromine salt, a nitrate salt, a tetrafluoroborate salt or a hexafluorophosphate salt of 1-aminoethyl-3-methylimidazole, preferably a bromine salt or a nitrate salt, more preferably a bromine salt.
According to the present invention, the 1-aminoethyl-3-methylimidazolium salt can be prepared according to the methods described in the literature (Solubility of carbon dioxide in amine-functionalized lipids: Role of the analogs, 2012,193-194: 267-275).
According to the invention, the drilling fluid is preferably a water-based drilling fluid, i.e. a multiphase dispersion based on water as the main matrix with the addition of various additives.
The above-described aqueous drilling fluid containing the shale inhibitor of the present invention may further comprise one or more conventionally used additives well known to those skilled in the art, and preferably the drilling fluid of the present invention contains one or more of bentonite, a viscosifier, an anti-sloughing agent, a fluid loss additive, a lubricant, a reservoir protectant, a weighting agent, and a pH adjuster.
The drilling fluid preferably adopts the following formula:
wherein the content of the first and second substances,
the bentonite is clay which takes montmorillonite as a main mineral component and has the functions of endowing the drilling fluid with viscous shear force and fluid loss wall-building property. For example, sodium bentonite and/or calcium bentonite may be used, and sodium bentonite is preferred. Preferably, the bentonite is used in an amount of 2 to 5 parts by weight, more preferably 3 to 4 parts by weight.
The viscosifier can improve the viscous shear force of the drilling fluid. For example, the polymer can be one or more of xanthan gum, welan gum, polyacrylamide potassium salt, polyanionic cellulose and a copolymer of acrylamide and sodium acrylate, and welan gum is preferred; preferably, the tackifier is used in an amount of 0.1 to 0.5 parts by weight, more preferably 0.2 to 0.3 parts by weight.
The anti-collapse agent can assist the shale inhibitor to prevent well wall collapse and improve the stability of the well wall. For example, the asphalt can be one or more of potassium humate, organosilicon, sulfonated asphalt and polymeric alcohol, and the sulfonated asphalt is preferred. Preferably, the anti-collapse agent is used in an amount of 1 to 5 parts by weight, more preferably 2 to 4 parts by weight.
The fluid loss additive can improve the fluid loss wall building property of the drilling fluid. For example, the resin may be one or more of sulfomethyl phenolic resin, sulfomethyl lignite and zwitterionic polymer, and is preferably a combination of sulfonated lignite resin and sulfonated phenolic resin. Preferably, the fluid loss additive is used in an amount of 1 to 8 parts by weight, more preferably 4 to 6 parts by weight.
The lubricant can improve the lubricating performance of the drilling fluid. The oil-water mixture can prevent the downhole complex conditions such as sticking, for example, one or more of fatty acid polyol ester, fatty alcohol, phosphate ester and diesel oil and surfactant mixture, and the fatty acid polyol ester is preferred. Preferably, the lubricant is used in an amount of 1 to 6 parts by weight, more preferably 2 to 4 parts by weight.
The reservoir protection agent can protect a reservoir and prevent the permeability and the porosity of the reservoir from being reduced due to the fact that drilling fluid and solid-phase particles invade the reservoir. For example, the water-soluble calcium carbonate can be one or more of superfine calcium carbonate, unidirectional pressure shielding temporary plugging agent and oil film temporary plugging agent, and is preferably oil film temporary plugging agent. Preferably, the content of the reservoir protection agent is 1-4 wt%, and more preferably 2-3 wt%.
The weighting agent can increase the drilling fluid density to balance formation pressure. For example, the material can be one or more of barite, iron ore powder and manganous-manganic oxide, and the barite is preferred. Preferably, the weighting agent is used in an amount of 0 to 40 parts by weight, more preferably 10 to 20 parts by weight.
The pH regulator can regulate the pH value of the drilling fluid to be in a weak alkaline range. For example, the catalyst may be one or more of sodium hydroxide, potassium hydroxide and lithium hydroxide, preferably potassium hydroxide. Preferably, the pH regulator is used in an amount of 0 to 0.5 parts by weight, more preferably 0.1 to 0.3 parts by weight.
The above additives may be commercially available ones or may be prepared according to a method conventional in the art, and will not be described herein.
In the drilling fluid, the content of bentonite is preferably 3-4 parts by weight. Preferably, the content of the shale inhibitor is 1-3 parts by weight. Preferably, the content of the tackifier is 0.2 to 0.3 parts by weight. Preferably, the content of the fluid loss additive is 4-6 parts by weight. Preferably, the anti-collapse agent is contained in an amount of 2 to 4 parts by weight. Preferably, the content of the lubricant is 2 to 4 parts by weight. Preferably, the content of the reservoir protection agent is 2-3 parts by weight. Preferably, the weight-increasing agent is contained in an amount of 10 to 20 parts by weight. Preferably, the content of the pH regulator is 0.1 to 0.3 parts by weight.
In a preferred embodiment of the invention, the drilling fluid is provided, and the drilling fluid contains 1-3 parts by weight of the shale inhibitor, 3-4 parts by weight of bentonite, 0.2-0.3 part by weight of welan gum, 2-4 parts by weight of sulfonated asphalt, 2-3 parts by weight of sulfomethyl lignite resin, 2-4 parts by weight of sulfomethyl phenolic resin, 2-4 parts by weight of fatty acid polyol ester, 2-3 parts by weight of calcium carbonate, 10-20 parts by weight of barite and 0.1-0.3 part by weight of potassium hydroxide.
The invention also aims to provide a preparation method of the drilling fluid.
The method comprises the following steps:
the components are mixed according to the using amount to prepare the drilling fluid.
The invention also aims to provide the application of the drilling fluid in petroleum drilling.
When the drilling fluid is used for drilling a large-section shale stratum which is easy to cause borehole wall instability, the surface hydration of montmorillonite in the shale can be effectively prevented, so that the drilling fluid has the effects of reducing the expansion pressure of the shale and maintaining the borehole wall stability.
Detailed Description
The present invention will be further described with reference to the following examples.
Preparation of 1-aminoethyl-3-methylimidazolium bromide salt:
placing a four-neck flask provided with a stirrer, a nitrogen guide pipe, a thermometer and a condenser in a constant-temperature water bath, adding 1-methylimidazole (8.20g, 0.10mol), 2-bromoethylamine hydrobromide (20.50g, 0.10mol) and 50mL of acetonitrile into the flask, stirring at 80 ℃ for 4 hours to ensure that the solution is layered, adding NaOH (4.0g, 0.10mol) into the mixture for neutralization, filtering to remove NaBr precipitate, pouring out the upper solution containing the residual reactant, and extracting the lower solution with acetonitrile (5mL multiplied by 3) to obtain 15.5g of waxy product, namely the shale inhibitor 1-aminoethyl-3-methylimidazole bromide.
Example 1
The 1-aminoethyl-3-methylimidazolium bromide salt prepared in preparation example was dissolved in tap water to prepare a1 wt% aqueous solution. The inhibitory effect was evaluated by selecting 5 parts of 300mL of a1 wt% aqueous solution of 1-aminoethyl-3-methylimidazolium bromide.
Comparative example 1
5 parts of 300mL tap water were used as reference sample.
Comparative example 2
An aqueous solution was prepared as in example 1, except that a small cation (2, 3-epoxypropyltrimethylammonium chloride, available from Shandong Langyue chemical Co., Ltd., the same applies hereinafter) shale inhibitor was dissolved in tap water.
Test example 1
The bentonite slurrying experiment is adopted to test the effect of the 1-aminoethyl-3-methylimidazole bromine salt on inhibiting the hydration and dispersion of the bentonite.
The test method comprises the following steps: to 5 parts of 300mL of a1 wt% 1-aminoethyl-3-methylimidazolium bromide aqueous solution sample in example 1 and 5 parts of 300mL of a1 wt% tap water sample in comparative example 1 and 5 parts of 300mL of a1 wt% small cation aqueous solution in comparative example 2 were added 12g, 24g, 36g, 48g and 60g of sodium bentonite (available from Weifang Huawei Bentonite GmbH) in this order, respectively, and stirred at 11000rpm for 20min and then hot rolled in a high-temperature roller oven at 80 ℃ for 16 h. Taking out, and testing with six-speed rotational viscometer (available from QINGDAOGUN Petroleum instruments Co., Ltd., brand ZNN-D6B) at 600 rpm of system
And 300 turns
Reading, measuring the dynamic shear value of the slurry according to the following formula, and the test result of the bentonite slurrying experiment is shown in a table 1,
TABLE 1
And "- -" is the meter dial reading out of the maximum range and cannot be calculated.
As can be seen from the table, the dynamic shear force of the bentonite after slurrying in the 1-aminoethyl-3-methylimidazolium bromide aqueous solution is obviously smaller than that of the bentonite in tap water and small cation aqueous solution, which shows that the shale inhibitor used in the drilling fluid has excellent inhibition performance and can effectively inhibit the hydration dispersion of the bentonite.
Example 2
The water-based drilling fluid is prepared according to the following formula: 100 parts by weight of water, 3 parts by weight of sodium bentonite, 0.2 part by weight of potassium hydroxide, 0.3 part by weight of welan gum, 3 parts by weight of sulfonated asphalt, 4 parts by weight of sulfonated phenol-formaldehyde resin, 2 parts by weight of sulfonated lignite resin, 2 parts by weight of pentaerythritol oleate, 3 parts by weight of calcium carbonate, 10 parts by weight of barite (the barium sulfate content is 93% by weight), and 1 part by weight of the shale inhibitor of the preparation example were added, respectively, to obtain a drilling fluid a 1.
Example 3
The water-based drilling fluid is prepared according to the following formula: 100 parts by weight of water, 3 parts by weight of sodium bentonite, 0.2 part by weight of potassium hydroxide, 0.3 part by weight of welan gum, 3 parts by weight of sulfonated asphalt, 4 parts by weight of sulfonated phenol-formaldehyde resin, 2 parts by weight of sulfonated lignite resin, 2 parts by weight of pentaerythritol oleate, 3 parts by weight of calcium carbonate, 10 parts by weight of barite (the barium sulfate content is 93% by weight), and 2 parts by weight of the shale inhibitor of the preparation example and the balance of water were added, respectively, to obtain a drilling fluid a 2.
Example 4
The water-based drilling fluid is prepared according to the following formula: 100 parts by weight of water, 3 parts by weight of sodium bentonite, 0.2 part by weight of potassium hydroxide, 0.3 part by weight of welan gum, 3 parts by weight of sulfonated asphalt, 4 parts by weight of sulfonated phenol-formaldehyde resin, 2 parts by weight of sulfonated lignite resin, 2 parts by weight of pentaerythritol oleate, 3 parts by weight of calcium carbonate, 10 parts by weight of barite (the barium sulfate content is 93% by weight), and 3 parts by weight of the shale inhibitor of the preparation example and the balance of water were added, respectively, to obtain a drilling fluid a 3.
Example 5
The water-based drilling fluid is prepared according to the following formula: 100 parts by weight of water, 2 parts by weight of sodium bentonite, 0.1 part by weight of welan gum, 1 part by weight of sulfonated asphalt, 0.5 part by weight of sulfonated phenolic resin, 0.5 part by weight of sulfonated lignite resin, 1 part by weight of pentaerythritol oleate, 1 part by weight of calcium carbonate, 10 parts by weight of barite (barium sulfate content: 93% by weight), and 0.5 part by weight of the shale inhibitor of the preparation example were added, respectively, to obtain a drilling fluid a 4.
Example 6
The water-based drilling fluid is prepared according to the following formula: 100 parts by weight of water, 5 parts by weight of sodium bentonite, 0.5 part by weight of potassium hydroxide, 0.5 part by weight of welan gum, 5 parts by weight of sulfonated asphalt, 4 parts by weight of sulfonated phenol resin, 4 parts by weight of sulfonated lignite resin, 6 parts by weight of pentaerythritol oleate, 4 parts by weight of calcium carbonate, 20 parts by weight of barite (the barium sulfate content is 93% by weight), and 5 parts by weight of the shale inhibitor of the preparation example were added, respectively, to obtain a drilling fluid a 5.
Comparative examples 3 to 5
According to the formulation described in application example 2, except that 5 parts by weight of potassium chloride, 1 part by weight of choline chloride or 1 part by weight of 2, 3-epoxypropyltrimethylammonium chloride were added instead of the shale inhibitor of the preparation example, drilling fluid DA1-DA3 was prepared.
Test example 2
The thermal rollback yields of drilling fluids A1 and DA1-DA3 were determined according to the method described in GB/T16783.1-2006 oil and gas industry drilling fluid field test part 1, water-based drilling fluids, respectively.
The method for measuring the hot roll back yield comprises the following steps: 350mL of the drilling fluid is put in a high-temperature tank, 50g of shale debris with 6-10 meshes is added into the high-temperature tank, hot rolling is carried out for 16h at 130 ℃, then the shale debris is sieved by a 40-mesh sieve, the shale debris is washed under tap water for about 2min, the residue of the sieve is dried to constant weight at 105 +/-3 ℃, and then weighing is carried out, and the hot rolling recovery rate R is calculated as the dried mass/dry weight before experiment. The greater the recovery rate, the greater the inhibition of the treating agent, and conversely, the poorer the inhibition.
TABLE 2
| Drilling fluid | Hot rollback yield/% |
| A1 | 71.2 |
| A2 | 82.5 |
| A3 | 85.7 |
| A4 | 59.5 |
| A5 | 94.5 |
| DA1 | 23.5 |
| DA2 | 45.7 |
| DA3 | 31.3 |
As can be seen from the data in table 2, the heat rollback yields of the drilling fluids a1, a2, A3, a4 and a5 using the shale inhibitor of the present application can reach 71.2%, 82.5%, 85.7%, 59.5% and 94.5%, respectively, thereby indicating that the drilling fluids have excellent properties of inhibiting shale from dispersing and maintaining borehole wall stability. While the drilling fluid DA1-DA3 without the shale inhibitor of the present application exhibited a heat rollback yield of only 23.5-45.7%, indicating relatively poor performance in shale inhibition.
The preferred embodiments of the present invention have been described in detail, however, the present invention is not limited to the specific details of the above embodiments, and various simple modifications may be made to the technical solution of the present invention within the technical idea of the present invention, and these simple modifications are within the protective scope of the present invention.
Claims (4)
1. A drilling fluid, characterized in that it comprises:
the components are calculated according to the parts by weight,
the shale inhibitor is 1-aminoethyl-3-methylimidazolium salt,
the structural formula is as follows:
wherein R is Br;
the bentonite is sodium bentonite and/or calcium bentonite;
the tackifier is one or a combination of xanthan gum, welan gum, polyacrylamide sylvite, polyanionic cellulose and a copolymer of acrylamide and sodium acrylate;
the anti-collapse agent is one or a combination of potassium humate, organic silicon and sulfonated asphalt;
the fluid loss additive is one or a combination of sulfomethyl phenolic resin, sulfomethyl lignite resin and zwitterionic polymer;
the lubricant is one or a combination of sulfonated oil residue, a mixture of diesel oil and a surfactant, and a mixture of fatty glyceride and a surfactant;
the reservoir protecting agent is one or a plurality of combinations of superfine calcium carbonate, a unidirectional pressure shielding temporary plugging agent and an oil film temporary plugging agent;
the weighting agent is one or a combination of more of barite, iron ore powder and manganous-manganic oxide;
the pH regulator is one or more of sodium hydroxide, potassium hydroxide and lithium hydroxide.
2. The drilling fluid of claim 1, wherein:
3. a method of preparing a drilling fluid according to any one of claims 1 to 2, wherein the method comprises:
the components are mixed according to the using amount to prepare the drilling fluid.
4. Use of a drilling fluid according to any one of claims 1 to 2 in oil drilling.
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| CN109824597B (en) * | 2019-01-30 | 2020-07-31 | 中国石油集团川庆钻探工程有限公司 | Modified polyhistidine suitable for being used as supermolecular shale inhibitor, preparation method thereof and application thereof in water-based drilling fluid |
| CN111909667B (en) * | 2019-05-07 | 2022-10-04 | 中国石油天然气集团有限公司 | Shale early hydration inhibitor composition and drilling fluid |
| US10889742B1 (en) | 2020-05-29 | 2021-01-12 | China University Of Petroleum (Beijing) | Modified polyhistidine suitable for being used as a supramolecular shale inhibitor, method of preparing the same and its application in water-based drilling fluids |
| CN111662690A (en) * | 2020-07-09 | 2020-09-15 | 南京良友化工有限公司 | High-temperature-resistant tackifier for drilling fluid and production method thereof |
| CN111978939B (en) * | 2020-09-16 | 2022-04-19 | 西南石油大学 | Polyion liquid used as surface hydration inhibitor and water-based drilling fluid system |
| CN116253877B (en) * | 2023-03-16 | 2024-03-19 | 中国石油大学(华东) | High-temperature-resistant low-viscosity hyperbranched polyion liquid inhibitor for water-based drilling fluid and preparation method and application thereof |
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| CN104497994A (en) * | 2014-11-19 | 2015-04-08 | 中国地质大学（北京） | Drilling fluid and application of ionic liquid in drilling fluid |
| WO2016196609A1 (en) * | 2015-06-01 | 2016-12-08 | Aramco Services Company | Compositions of and methods for making stable carbonaceous nanomaterials |
| CN105038739A (en) * | 2015-07-15 | 2015-11-11 | 中国地质大学（北京） | Drilling fluid and use of imidazole ionic liquid therein |
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