CN113956858A - While-drilling pressure-bearing composite plugging agent for oil-based drilling fluid and preparation method thereof - Google Patents
While-drilling pressure-bearing composite plugging agent for oil-based drilling fluid and preparation method thereof Download PDFInfo
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- 239000012530 fluid Substances 0.000 title claims abstract description 55
- 239000002131 composite material Substances 0.000 title claims abstract description 27
- 238000002360 preparation method Methods 0.000 title claims abstract description 10
- 239000002245 particle Substances 0.000 claims abstract description 28
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 27
- 239000010426 asphalt Substances 0.000 claims abstract description 19
- 239000011882 ultra-fine particle Substances 0.000 claims abstract description 14
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- 229910000019 calcium carbonate Inorganic materials 0.000 claims description 8
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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
- C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
- C09K8/426—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells for plugging
-
- 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
- C09K8/32—Non-aqueous well-drilling compositions, e.g. oil-based
-
- 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
- C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
- C09K8/46—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
Abstract
The invention discloses a pressure-bearing while-drilling composite plugging agent for oil-based drilling fluid and a preparation method thereof, wherein the pressure-bearing while-drilling composite plugging agent is a composite product prepared from rigid ultrafine particles, elastic particles, micro fibers and emulsified asphalt through a double-helix conical mixer; the plugging while drilling improves the stratum bearing capacity, has good compatibility with other treating agents, and has low viscosity effect on the oil-based drilling fluid.
Description
Technical Field
The invention relates to the technical field of drilling fluid and completion fluid in petroleum and natural gas drilling engineering, in particular to a pressure-bearing while drilling composite plugging agent for an oil-based drilling fluid and a preparation method thereof.
Background
Shale gas resource reserves in China are abundant, geological resource reserves are preliminarily predicted to be about 134 multiplied by 1012m3, the technical recoverable reserve can be up to about 25 multiplied by 1012m3, and the shale gas resource reserves have wide development prospects and are important measures for solving the shortage of oil gas resources in China, realizing the increase of oil gas storage and production and guaranteeing the national energy safety.
According to statistics, China has the shale gas resource prospect and the development potential which are about the same as those of the United states, the total area of the shale gas resource in China reaches 300 multiplied by 104km2, the resource distribution is wide, and the potential is huge. At present, the shale gas exploration and development in China mainly focuses on the places such as the Sichuan basin and the periphery thereof, the Erdos basin, the eastern depression of the Liaohe and the like, and in the last 10 years, the shale gas resource development in the areas of Sichuan, Chongqing and the like in the southwest area of China with the vertical depth of less than 3500m has already been primarily achieved.
However, although shale is very dense, the matrix pores are mainly nano-sized and contain a small amount of micro-sized pores, the research results show that the permeability of the shale matrix is between (10 < -9 > -10 < -5 >) and 10 < -3 > mu m2, the permeability of cracks is generally between (10 < -3 > -10 < -1 >) and 10 < -3 > mu m2, and the difference between the two permeabilities reaches more than 3 orders of magnitude.
Therefore, when the stratum is drilled and the shale stratum is contacted with the drilling fluid filtrate, the drilling fluid filtrate can be preferentially leaked into the stratum from the microcracks with better permeability under the action of capillary force and positive pressure difference, the pore pressure of the stratum is increased, and a series of physical and chemical actions are generated between the subsequent drilling fluid filtrate and the shale, so that the stability of the well wall is obviously influenced.
Secondly, the shale stratum and the developed micro cracks and the extension and the expansion of the micro cracks are important reasons for the well leakage in the drilling process of the shale stratum. After the drilling fluid enters the stratum through the microcracks and the microcracks under the leakage action, the bonding force among shale stratum particles is reduced, the bonding force of weak structural surfaces such as the microcracks and the like and the internal friction angle are reduced, and the friction strength is reduced. When the shale stratum is subjected to large stress, the tips of the micro cracks can generate large stress concentration, when the stress is greater than the strength of the hydrated rock, the micro cracks can extend and expand and are communicated with each other, and finally the micro cracks are communicated with the main cracks, and finally the stratum is damaged along the cracks with the weakest mechanical property, so that the conditions of well wall chipping and the like are caused.
In addition, because the shale stratum has a strong hydration function with water, at present, oil-based drilling fluid or synthetic-based drilling fluid is often used in the drilling process, which mainly solves the problem of instability of shale well walls to a certain extent by using the oil-based drilling fluid and the synthetic-based drilling fluid, because the oil-based drilling fluid can improve the capillary force of the water-wet shale and prevent the drilling fluid from invading the shale.
However, even with oil-based drilling fluids, the plugging of fractured or bedding developing shale formations must be enhanced to reduce pressure transmission (block fluid pathways) by the fluid entering the formation. However, the oil-based drilling fluid plugging technology is still imperfect, and many traditional plugging materials cannot be used in the oil-based drilling fluid or have poor field application effect, especially the leak-proof plugging materials while drilling. Therefore, the oil-based drilling fluid cannot well solve the problem of well wall stability of the shale gas formation with cracks and bedding development.
Disclosure of Invention
The invention aims to provide a pressure-bearing while-drilling composite plugging agent for an oil-based drilling fluid and a preparation method thereof, and aims to solve the problem that the oil-based drilling fluid cannot well solve the problem of stability of a shale gas formation well wall in crack and bedding development.
In order to achieve the purpose, the invention provides the following technical scheme: a pressure-bearing while-drilling composite plugging agent for oil-based drilling fluid is a composite product prepared from rigid superfine particles, elastic particles, micro fibers and emulsified asphalt by a double-helix conical mixer;
wherein the mass ratio of the rigid ultrafine particles, the elastic particles, the fine fibers and the emulsified asphalt is (0.5-2): (2-4): (1.5-6): and (3-6) adding the rigid ultrafine particles, the elastic particles, the micro fibers and the emulsified asphalt raw materials into a double-helix conical mixer according to the proportion, and mixing for 2-4 hours.
Further, the rigid ultrafine particles are ultrafine calcium carbonate, ultrafine quartz powder or ultrafine calcite powder, and the elastic particles are elastic graphite.
Furthermore, the D90 value of the rigid superfine particles is less than or equal to 40 mu m, the D90 value of the elastic particles is less than or equal to 40 mu m, the fiber diameter of the microfine fibers is less than or equal to 2 mu m, the fiber length of the microfine fibers is less than or equal to 5mm, and the asphaltene softening point of the emulsified asphalt is less than or equal to 150 ℃ at 120 ℃.
Furthermore, the pressure-bearing while drilling composite plugging agent is a black viscous solid in appearance, the density is 2.40-2.60 g/cm3, the water content is less than or equal to 12%, the depth of sand bed invasion is less than or equal to 2cm, the loss of a PPA sand disc is less than or equal to 10mL, and the viscosity effect on the oil-based drilling fluid is less than or equal to 30%.
A pressure-bearing while drilling composite plugging agent for oil-based drilling fluid and a preparation method thereof are disclosed, wherein the preparation method comprises the following steps:
s1, placing the emulsified asphalt with the softening point of 120-150 ℃ into a double-helix conical mixer, starting a stirrer, stirring for 10min, adding rigid ultrafine particles with a certain proportion, and meshing and stirring for 10 min;
s2, adding the elastic particles into a double-helix conical mixer according to the proportion, and meshing and stirring for 30 min;
and S3, adding the micro-fibers in a certain ratio into a double-helix conical mixer, meshing and stirring for 60-90 min, and discharging to obtain the pressure-bearing while drilling composite plugging agent for the oil-based drilling fluid.
Compared with the prior art, the invention has the beneficial effects that:
the plugging while drilling improves the stratum bearing capacity, has good compatibility with other treating agents, and has low viscosity effect on the oil-based drilling fluid.
Detailed Description
In the case of the example 1, the following examples are given,
in the embodiment of the invention, the pressure-bearing while-drilling composite plugging agent for the oil-based drilling fluid is a composite product prepared from rigid ultrafine particles, elastic particles, microfine fibers and emulsified asphalt through a double-helix conical mixer;
wherein the mass ratio of the rigid ultrafine particles, the elastic particles, the fine fibers and the emulsified asphalt is (0.5-2): (2-4): (1.5-6): and (3-6) adding the rigid ultrafine particles, the elastic particles, the micro fibers and the emulsified asphalt raw materials into a double-helix conical mixer according to the proportion, and mixing for 2-4 hours.
Starting a double-helix conical mixer, weighing 45kg of emulsified asphalt (the softening point is 120-150 ℃) and placing the emulsified asphalt in the double-helix conical mixer, stirring for 10min, weighing 12kg of ultrafine calcium carbonate particles (the D90 value is less than or equal to 40 mu m) and placing the ultrafine calcium carbonate particles in the double-helix conical mixer, and meshing and mixing for 10 min; and then weighing 30kg of elastic graphite according to a ratio, adding the elastic graphite into a double-helix conical mixer, meshing and stirring for 30min, finally weighing 20kg of micro-fibers, putting the micro-fibers into the double-helix conical mixer, meshing and stirring for 60-90 min, and discharging to obtain the pressure-bearing while drilling composite plugging agent for the oil-based drilling fluid.
Examples 2,
Starting a double-helix conical mixer, weighing 50kg of emulsified asphalt (the softening point is 120-150 ℃) and placing the emulsified asphalt in the mixer, stirring the mixture for 10min, and weighing 18kg of ultrafine calcium carbonate particles (D)90The value is less than or equal to 40 mu m) is placed in a double-helix conical mixer and is meshed and mixed for 10 min; then, 55kg of elastic graphite is weighed and added according to the proportionAnd (3) meshing and stirring for 30min in a double-helix conical mixer, finally weighing 18kg of micro-fibers, putting the micro-fibers into the double-helix conical mixer, meshing and stirring for 60-90 min, and discharging to obtain the pressure-bearing while drilling composite plugging agent for the oil-based drilling fluid.
Examples 3,
And (4) determining the change rate of the apparent viscosity.
1. The formula of the experimental slurry of the oil-based drilling fluid comprises the following components: 400mL of white oil (No. 5) + 4% of main emulsifier + 4% of auxiliary emulsifier + 1% of flow pattern modifier + 4% of fluid loss additive + 3% of organic soil + 10% of calcium chloride brine + 3% of lime + barite is weighted to 1.25g/cm 3.
2. Preparing oil-based drilling fluid experimental slurry: adding white oil, main emulsion and auxiliary emulsion into 1 high-speed stirring cup, stirring at high speed for 30min, sequentially adding shear-promoting agent, filtrate reducer and organic soil, adding calcium chloride water and lime together, stirring for 30min, adding barite, and stirring for 30 min.
3. Taking 1 part of the experimental slurry, stirring at a high speed for 20min, placing the experimental slurry into a roller furnace for aging at 180 ℃/16h, and testing the apparent viscosity of the experimental slurry at 65 ℃ after aging according to the method specified by GBT 16783.2-2012, and recording the apparent viscosity as AV-1.
4. And adding 15.0g of sample into 1 part of experimental slurry, stirring at a high speed for 20min, aging in a roller furnace at 180 ℃/16h, stirring at a high speed for 20min, and testing the apparent viscosity at 65 ℃ according to a method specified by GBT 16783.2-2012, wherein the apparent viscosity is recorded as AV-2.
The results of the experiment are shown in table 1.
TABLE 1 apparent viscosity Change Rate test results
From the results in Table 1, it is understood that the apparent viscosity change rates of the test slurries added to the samples of example 1 and example 2 were 23.1% and 28.8%, respectively, and the apparent viscosity change rates were less than 30%.
Examples 4,
And (4) measuring the invasion depth of the sand bed.
1.2 parts of experimental slurry were prepared as in example 3.
2. Pouring 40-60-mesh quartz sand into a drilling fluid sand bed filtration loss instrument, paving, compacting, keeping the height (20.0 +/-1.0) cm of a sand bed, putting 1 part of experimental slurry into a roller furnace, aging at 180 ℃/16H, stirring at a high speed for 20min, slowly pouring 150mL of prepared experimental slurry, tightening a cup cover, opening a lower valve rod, connecting an air source, slowly adjusting the pressure to 0.7MPa, opening an upper valve rod, keeping for 30min, and measuring the maximum invasion depth of the sand bed, wherein the maximum invasion depth is recorded as H-1.
3. And adding 15.0g of sample into 1 part of the experimental slurry, stirring at a high speed for 20min, placing the mixture into a roller furnace for aging at 180 ℃/16H, stirring at a high speed for 20min, and measuring the maximum invasion depth of the sand bed according to the method in the step 2 and recording as H-2.
The results of the experiment are shown in table 2.
TABLE 2 Sand bed invasion depth test results
As is clear from Table 2, the sand bed invasion depths of the test slurries added to the samples of examples 1 and 2 were each less than 2cm, and the sand bed invasion depth reduction rate was as high as 68.7% or more.
Examples 5,
And measuring the PPA sand disc filtration loss.
1.2 portions of experimental slurry were prepared as in example 3.
2. Taking a sand disc with the permeability of 10 mu m2 as an evaluation medium, putting 1 part of experimental slurry into a roller furnace, aging at 180 ℃/16h, stirring at a high speed for 20min, testing the PPA sand disc filtration loss at 180 ℃/6.9MPa according to the requirement of GB/T29170-.
3. Taking 1 part of the experimental slurry, adding 15.0g of sample, stirring at high speed for 20min, placing the sample in a roller furnace for aging at 180 ℃/16h, stirring at high speed for 20min, testing the PPA sand disc filtration loss under 180 ℃/6.9MPa according to the requirement of GB/T29170-.
The results of the experiment are shown in table 3.
TABLE 3 Sand bed invasion depth test results
As can be seen from table 2, the PPA leakage amount of the experimental slurry added in the example 1 sample and the example 2 sample is less than 5mL, and is 2.6mL and 3.2mL, respectively, and the reduction rate of the PPA leakage amount is as high as more than 60%, which indicates that the example 1 sample and the example 2 sample have significant plugging effects, and the test result of the example 3 indicates that the example 1 sample and the example 2 sample have significant effects of improving the plugging while drilling of the oil-based drilling fluid.
Examples 6,
Performance in high temperature high density oil-based drilling fluid formulations.
1. The formula of the high-temperature high-density oil-based drilling fluid system comprises the following components: 320mL of No. 5 white oil, 12g of a main emulsifier HIEMUL, 12g of an auxiliary emulsifier HICOAT, 12g of a wetting agent HIWET, 80mL of 25% CaCl2 saline water, 12g of organic soil, 16g of a fluid loss additive BZ-PFL, 8g of a flow type regulator BZ-ORM, 20g of the sample of example 1, 12g of a composite plugging agent with a variable particle size CLG-NM, 8g of lime, 12g of superfine calcium carbonate and barite are weighted to 2.2g/cm 3.
2. The preparation method of the high-temperature high-density oil-based drilling fluid system comprises the following steps: adding 320mL of No. 5 white oil, 12g of main emulsifier HIEMUL, 12g of auxiliary emulsifier HICOAT and 12g of wetting agent HIWET into a high-stirring cup, stirring at a high speed (8000-12000 rpm) for 30min, adding 80mL of 25% CaCl2 saline, and stirring at a high speed for 30min to form a stable emulsion system; then, respectively adding 12g of organic soil, 16g of fluid loss additive BZ-PFL, 8g of flow pattern regulator BZ-ORM, 20g of sample of example 1, 12g of particle size variable composite plugging agent CLG-NM, 8g of lime and 12g of superfine calcium carbonate into a high-stirring cup in sequence, wherein after adding each treating agent, stirring at a high speed for 20min, adding the other treating agent; and finally, weighting the oil-based drilling fluid to 2.2g/cm3 by using API standard barite, and stirring at a high speed for 30min to obtain the oil-based high-temperature high-density drilling fluid system. As a test slurry for the following drilling fluid performance tests.
3. Testing basic performance of the drilling fluid:
and (3) putting the prepared drilling fluid into an aging tank, respectively carrying out hot rolling for 16 hours at 150 ℃ and 180 ℃, cooling to room temperature, and transferring into a high-speed stirring cup to stir for 20 minutes at a high speed. The viscosity, shear force, medium pressure fluid loss and high temperature and high pressure fluid loss (180 ℃/3.5MPa) of each test slurry were measured, wherein the test temperature for rheology was 65 ℃, and the test results are shown in table 4.
Drilling fluid Performance test results in Table 4
As can be seen from Table 4, after the test slurry is aged at high temperature, the apparent viscosity and the plastic viscosity are slightly increased, the dynamic shear force is maintained at 11-20.5Pa, the initial cut and the final cut are basically kept stable, the API (American petroleum institute) filtration loss is 0mL, the HTHP filtration loss is less than 3mL, the breaking voltage shows a trend of gradually increasing along with the continuous increase of the high-temperature aging temperature, and the emulsion of the oil-based high-temperature high-density drilling fluid system is more excellent in stability under the high-temperature condition.
In the combination of example 1-example 6, the rigid ultrafine particles are ultrafine calcium carbonate, ultrafine quartz powder, or ultrafine calcite powder, and the elastic particles are elastic graphite.
The D90 value of the rigid superfine particles is less than or equal to 40 mu m, the D90 value of the elastic particles is less than or equal to 40 mu m, the fiber diameter of the superfine fibers is less than or equal to 2 mu m, the fiber length of the superfine fibers is less than or equal to 5mm, and the asphaltene softening point of the emulsified asphalt is less than or equal to 150 ℃ at 120 ℃.
Furthermore, the pressure-bearing while drilling composite plugging agent is a black viscous solid in appearance, the density is 2.40-2.60 g/cm3, the water content is less than or equal to 12%, the depth of sand bed invasion is less than or equal to 2cm, the loss of a PPA sand disc is less than or equal to 10mL, and the viscosity effect on the oil-based drilling fluid is less than or equal to 30%.
It will be evident to those skilled in the art that the invention is not limited to the details of the foregoing illustrative embodiments, and that the present invention may be embodied in other specific forms without departing from the spirit or essential attributes thereof. The present embodiments are therefore to be considered in all respects as illustrative and not restrictive, the scope of the invention being indicated by the appended claims rather than by the foregoing description, and all changes which come within the meaning and range of equivalency of the claims are therefore intended to be embraced therein. Any reference sign in a claim should not be construed as limiting the claim concerned.
Furthermore, it should be understood that although the present description refers to embodiments, not every embodiment may contain only a single embodiment, and such description is for clarity only, and those skilled in the art should integrate the description, and the embodiments may be combined as appropriate to form other embodiments understood by those skilled in the art.
Claims (5)
1. The pressure-bearing while-drilling composite plugging agent for the oil-based drilling fluid is characterized by being a composite product prepared from rigid superfine particles, elastic particles, micro fibers and emulsified asphalt through a double-helix conical mixer;
wherein the mass ratio of the rigid ultrafine particles, the elastic particles, the fine fibers and the emulsified asphalt is (0.5-2): (2-4): (1.5-6): and (3-6) adding the rigid ultrafine particles, the elastic particles, the micro fibers and the emulsified asphalt raw materials into a double-helix conical mixer according to the proportion, and mixing for 2-4 hours.
2. The pressure-bearing while drilling composite plugging agent for the oil-based drilling fluid as claimed in claim 1, wherein the rigid ultrafine particles are ultrafine calcium carbonate, ultrafine quartz powder or ultrafine calcite powder, and the elastic particles are elastic graphite.
3. The pressure-bearing while drilling composite plugging agent for the oil-based drilling fluid as claimed in claim 1, wherein the D90 value of the rigid ultrafine particles is less than or equal to 40 μm, the D90 value of the elastic particles is less than or equal to 40 μm, the fiber diameter of the microfine fibers is less than or equal to 2 μm, the fiber length of the microfine fibers is less than or equal to 2mm, and the asphaltene softening point of the emulsified asphalt is less than or equal to 150 ℃ at 120 ℃.
4. The pressure-bearing while-drilling composite plugging agent for the oil-based drilling fluid is characterized in that the pressure-bearing while-drilling composite plugging agent is a black viscous solid in appearance, has the density of 2.40-2.60 g/cm3, has the moisture content of less than or equal to 12%, has the sand bed penetration depth of less than or equal to 2cm, has the PPA sand disc leakage amount of less than or equal to 10mL, and has the viscosity effect on the oil-based drilling fluid of less than or equal to 30%.
5. The pressure-bearing while drilling composite plugging agent for the oil-based drilling fluid as claimed in any one of claims 1 to 4 and the preparation method thereof are characterized in that the preparation method comprises the following steps:
s1, placing the emulsified asphalt with the softening point of 120-150 ℃ into a double-helix conical mixer, starting a stirrer, stirring for 10min, adding rigid ultrafine particles with a certain proportion, and meshing and stirring for 10 min;
s2, adding the elastic particles into a double-helix conical mixer according to the proportion, and meshing and stirring for 30 min;
and S3, adding the micro-fibers in a certain ratio into a double-helix conical mixer, meshing and stirring for 60-90 min, and discharging to obtain the pressure-bearing while drilling composite plugging agent for the oil-based drilling fluid.
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| CN105419753A (en) * | 2015-10-23 | 2016-03-23 | 中国石油大学(华东) | novel leakage-preventing while drilling agent for oil-based drilling fluid and application |
| CN105524600A (en) * | 2016-02-24 | 2016-04-27 | 中石化重庆涪陵页岩气勘探开发有限公司 | Plugging while drilling agent for oil-based drilling fluid and preparation method of plugging while drilling agent |
| CN111849432A (en) * | 2020-07-30 | 2020-10-30 | 长江大学 | Acid-soluble while-drilling plugging agent and preparation method and application thereof |
| CN112745814A (en) * | 2019-10-30 | 2021-05-04 | 中国石油化工股份有限公司 | Plugging agent for oil-based drilling fluid and application |
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2021
- 2021-08-09 CN CN202110910040.XA patent/CN113956858A/en active Pending
Patent Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN105419753A (en) * | 2015-10-23 | 2016-03-23 | 中国石油大学(华东) | novel leakage-preventing while drilling agent for oil-based drilling fluid and application |
| CN105524600A (en) * | 2016-02-24 | 2016-04-27 | 中石化重庆涪陵页岩气勘探开发有限公司 | Plugging while drilling agent for oil-based drilling fluid and preparation method of plugging while drilling agent |
| CN112745814A (en) * | 2019-10-30 | 2021-05-04 | 中国石油化工股份有限公司 | Plugging agent for oil-based drilling fluid and application |
| CN111849432A (en) * | 2020-07-30 | 2020-10-30 | 长江大学 | Acid-soluble while-drilling plugging agent and preparation method and application thereof |
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