CN115093840A - Compressible drilling fluid and preparation method thereof - Google Patents
Compressible drilling fluid and preparation method thereof Download PDFInfo
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- CN115093840A CN115093840A CN202111495661.2A CN202111495661A CN115093840A CN 115093840 A CN115093840 A CN 115093840A CN 202111495661 A CN202111495661 A CN 202111495661A CN 115093840 A CN115093840 A CN 115093840A
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- drilling fluid
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- compressible
- regulator
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- 239000012530 fluid Substances 0.000 title claims abstract description 75
- 238000005553 drilling Methods 0.000 title claims abstract description 74
- 238000002360 preparation method Methods 0.000 title claims abstract description 17
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 27
- 239000000654 additive Substances 0.000 claims abstract description 26
- 230000000996 additive effect Effects 0.000 claims abstract description 26
- 239000000440 bentonite Substances 0.000 claims abstract description 16
- 229910000278 bentonite Inorganic materials 0.000 claims abstract description 16
- SVPXDRXYRYOSEX-UHFFFAOYSA-N bentoquatam Chemical compound O.O=[Si]=O.O=[Al]O[Al]=O SVPXDRXYRYOSEX-UHFFFAOYSA-N 0.000 claims abstract description 16
- 239000002002 slurry Substances 0.000 claims abstract description 16
- 150000003839 salts Chemical class 0.000 claims abstract description 15
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 14
- 239000003112 inhibitor Substances 0.000 claims abstract description 13
- 239000003638 chemical reducing agent Substances 0.000 claims abstract description 12
- 239000000706 filtrate Substances 0.000 claims abstract description 12
- 239000000126 substance Substances 0.000 claims abstract description 5
- 239000002994 raw material Substances 0.000 claims abstract description 3
- QTBSBXVTEAMEQO-UHFFFAOYSA-N Acetic acid Chemical compound CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 claims description 12
- 229920002401 polyacrylamide Polymers 0.000 claims description 11
- KWYUFKZDYYNOTN-UHFFFAOYSA-M Potassium hydroxide Chemical group [OH-].[K+] KWYUFKZDYYNOTN-UHFFFAOYSA-M 0.000 claims description 9
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 claims description 8
- 239000000843 powder Substances 0.000 claims description 8
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims description 7
- 239000002245 particle Substances 0.000 claims description 7
- 238000002347 injection Methods 0.000 claims description 5
- 239000007924 injection Substances 0.000 claims description 5
- 239000007788 liquid Substances 0.000 claims description 5
- 238000002156 mixing Methods 0.000 claims description 5
- 239000003922 charged colloid Substances 0.000 claims description 4
- 239000003607 modifier Substances 0.000 claims description 4
- 239000011780 sodium chloride Substances 0.000 claims description 4
- HRPVXLWXLXDGHG-UHFFFAOYSA-N Acrylamide Chemical compound NC(=O)C=C HRPVXLWXLXDGHG-UHFFFAOYSA-N 0.000 claims description 3
- 235000019738 Limestone Nutrition 0.000 claims description 3
- TZCXTZWJZNENPQ-UHFFFAOYSA-L barium sulfate Chemical compound [Ba+2].[O-]S([O-])(=O)=O TZCXTZWJZNENPQ-UHFFFAOYSA-L 0.000 claims description 3
- 239000010428 baryte Substances 0.000 claims description 3
- 229910052601 baryte Inorganic materials 0.000 claims description 3
- AXCZMVOFGPJBDE-UHFFFAOYSA-L calcium dihydroxide Chemical compound [OH-].[OH-].[Ca+2] AXCZMVOFGPJBDE-UHFFFAOYSA-L 0.000 claims description 3
- 239000000920 calcium hydroxide Substances 0.000 claims description 3
- 229910001861 calcium hydroxide Inorganic materials 0.000 claims description 3
- 238000013329 compounding Methods 0.000 claims description 3
- 238000001816 cooling Methods 0.000 claims description 3
- GUJOJGAPFQRJSV-UHFFFAOYSA-N dialuminum;dioxosilane;oxygen(2-);hydrate Chemical compound O.[O-2].[O-2].[O-2].[Al+3].[Al+3].O=[Si]=O.O=[Si]=O.O=[Si]=O.O=[Si]=O GUJOJGAPFQRJSV-UHFFFAOYSA-N 0.000 claims description 3
- 238000001035 drying Methods 0.000 claims description 3
- 238000000227 grinding Methods 0.000 claims description 3
- 239000006028 limestone Substances 0.000 claims description 3
- 238000002844 melting Methods 0.000 claims description 3
- 230000008018 melting Effects 0.000 claims description 3
- 229910052901 montmorillonite Inorganic materials 0.000 claims description 3
- TWNQGVIAIRXVLR-UHFFFAOYSA-N oxo(oxoalumanyloxy)alumane Chemical compound O=[Al]O[Al]=O TWNQGVIAIRXVLR-UHFFFAOYSA-N 0.000 claims description 3
- CHWRSCGUEQEHOH-UHFFFAOYSA-N potassium oxide Chemical compound [O-2].[K+].[K+] CHWRSCGUEQEHOH-UHFFFAOYSA-N 0.000 claims description 3
- 229910001950 potassium oxide Inorganic materials 0.000 claims description 3
- 239000000377 silicon dioxide Substances 0.000 claims description 3
- 235000012239 silicon dioxide Nutrition 0.000 claims description 3
- KKCBUQHMOMHUOY-UHFFFAOYSA-N sodium oxide Chemical compound [O-2].[Na+].[Na+] KKCBUQHMOMHUOY-UHFFFAOYSA-N 0.000 claims description 3
- 229910001948 sodium oxide Inorganic materials 0.000 claims description 3
- ZLMJMSJWJFRBEC-UHFFFAOYSA-N Potassium Chemical compound [K] ZLMJMSJWJFRBEC-UHFFFAOYSA-N 0.000 claims description 2
- 239000011591 potassium Substances 0.000 claims description 2
- 229910052700 potassium Inorganic materials 0.000 claims description 2
- 230000008961 swelling Effects 0.000 claims description 2
- 238000004519 manufacturing process Methods 0.000 abstract description 4
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical compound [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 description 6
- 230000006835 compression Effects 0.000 description 5
- 238000007906 compression Methods 0.000 description 5
- 230000015572 biosynthetic process Effects 0.000 description 4
- 239000002893 slag Substances 0.000 description 4
- 230000000694 effects Effects 0.000 description 3
- 239000003921 oil Substances 0.000 description 3
- 235000017550 sodium carbonate Nutrition 0.000 description 3
- 229910000029 sodium carbonate Inorganic materials 0.000 description 3
- 238000012360 testing method Methods 0.000 description 3
- 230000004075 alteration Effects 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 239000004927 clay Substances 0.000 description 2
- 238000005520 cutting process Methods 0.000 description 2
- 238000000034 method Methods 0.000 description 2
- 239000003002 pH adjusting agent Substances 0.000 description 2
- 238000000746 purification Methods 0.000 description 2
- 239000011734 sodium Substances 0.000 description 2
- 229910052708 sodium Inorganic materials 0.000 description 2
- 238000003756 stirring Methods 0.000 description 2
- 230000002277 temperature effect Effects 0.000 description 2
- 238000005299 abrasion Methods 0.000 description 1
- 238000009825 accumulation Methods 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000006185 dispersion Substances 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 230000003311 flocculating effect Effects 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 230000036571 hydration Effects 0.000 description 1
- 238000006703 hydration reaction Methods 0.000 description 1
- 230000002401 inhibitory effect Effects 0.000 description 1
- 229910052500 inorganic mineral Inorganic materials 0.000 description 1
- 239000011707 mineral Substances 0.000 description 1
- 235000010755 mineral Nutrition 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- XAEFZNCEHLXOMS-UHFFFAOYSA-M potassium benzoate Chemical compound [K+].[O-]C(=O)C1=CC=CC=C1 XAEFZNCEHLXOMS-UHFFFAOYSA-M 0.000 description 1
- 230000001376 precipitating effect Effects 0.000 description 1
- 238000001556 precipitation Methods 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 239000000047 product Substances 0.000 description 1
- 230000001007 puffing effect Effects 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 239000012798 spherical particle Substances 0.000 description 1
- 239000000725 suspension Substances 0.000 description 1
Classifications
-
- 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
Abstract
The invention discloses a compressible drilling fluid and a preparation method thereof, wherein the raw materials comprise the following substances: bentonite slurry, a treating agent, a drilling fluid additive, a flow pattern regulator, a temperature-resistant and salt-resistant filtrate reducer, a hydrate inhibitor, a pH regulator and water. The drilling fluid has certain compressibility. When the deepwater oil-gas well is in production operation, the bottom temperature is high, heat is transferred outwards, the drilling fluid in the annular space is heated and pressed, the pressed volume of an additive in the drilling fluid is reduced, the pressure bearing capacity of the drilling fluid is increased, and the stability of a shaft is guaranteed.
Description
Technical Field
The invention belongs to the technical field of drilling engineering, and particularly relates to a compressible drilling fluid and a preparation method thereof.
Background
Due to the influence of ocean deep water, a deep water oil and gas well shaft has a temperature gradient along the axial direction, the temperature of a seabed mud line, namely the temperature near the mud surface at the bottom of deep water, is generally between 2 and 4 ℃, and the temperature of formation fluid is often over 100 ℃. When the deepwater oil-gas well is tested or produced, high-temperature and high-Pressure formation fluid flows through a shaft from an oil pipe, the fluid in the enclosed ring spaces is heated, the fluid is heated and expanded to generate additional Pressure load, and the Annular Pressure Build-up (APB) is the phenomenon of fluid temperature rise and expansion in the enclosed ring spaces caused by the temperature effect. The annular stress accumulation can act on the casing, so that underground safety accidents such as casing collapse or expansion crack and the like are easily caused, and serious hidden danger is brought to safety production. Therefore, a compressible drilling fluid is developed, in the testing and production processes of deep water oil and gas wells, the drilling fluid is heated in an annular space, the pressure is increased, the volume of a novel additive in the drilling fluid is reduced, a certain volume allowance is provided for a closed annular space, and the integrity of a shaft is improved.
Disclosure of Invention
The invention provides a compressible drilling fluid, which aims to overcome the problems that the pressure is increased and the integrity of a shaft is damaged due to the increase of the annular temperature generated by the shaft temperature effect of a deepwater oil-gas well. The drilling fluid is added with the additive in the hollow particle drilling fluid, and the volume of the drilling fluid is reduced after being pressed due to the hollow structure, so that the drilling fluid contains more additive particles, a certain pressure-bearing space is provided, the pressure on the annular wall is reduced, and the integrity of a shaft is improved.
The invention is realized by the following technical scheme:
a compressible drilling fluid comprises the following raw materials: bentonite slurry, a treating agent, a drilling fluid additive, a flow pattern regulator, a temperature-resistant and salt-resistant filtrate reducer, a hydrate inhibitor, a pH regulator and water.
Further, the drilling fluid comprises 1-4% of bentonite slurry, 0.3% of treating agent, 2% of drilling fluid additive, 3% of flow pattern regulator, 3% of temperature-resistant and salt-resistant filtrate reducer, 0.01% -6% of hydrate inhibitor, 20% of pH regulator and the balance of water in percentage by volume.
Further, the bentonite slurry contains 85-90% of montmorillonite by mass percent.
Further, the treating agent is hydrolyzed potassium polyacrylamide (K-PAM).
Further, the drilling fluid additive comprises 50-65% of silicon dioxide, 6-8% of aluminum oxide, 15-20% of sodium oxide, 5-10% of potassium oxide, 2-3% of barite and 1-2% of limestone by mass. The preparation method comprises the following steps: crushing and mixing the substances, drying at high temperature, adding rubber powder, grinding the rubber powder into millimeter-sized particles through a ball mill, performing high-temperature melting at the temperature of more than 1000 ℃ after swelling, and finally cooling to obtain the additive, wherein the addition mass of the rubber powder is 35-60% of that of the flow pattern regulator.
Further, the flow pattern modifier includes positive charged colloid MMH and polyacrylamide PAM.
Further, the temperature-resistant and salt-resistant filtrate reducer KFH-1.
Further, the hydrate inhibitor is obtained by compounding sodium chloride and acetic acid.
Further, the pH regulator is potassium hydroxide and/or calcium hydroxide.
A preparation method of a compressive drilling fluid comprises the following steps:
adding water into a liquid preparation tank truck by using a water injection pump, adding 1-4% of bentonite slurry, 0.3% of treating agent, 2% of drilling fluid additive, 3% of flow pattern regulator, 3% of temperature-resistant and salt-resistant filtrate reducer, 0.01-6% of hydrate inhibitor, 20% of pH regulator and the balance of water into the water according to volume percentage, and mixing to obtain the compressible drilling fluid.
Compared with the prior art, the invention has the advantages that:
the invention discloses a compressible drilling fluid and a preparation method thereof. When the deepwater oil-gas well is in production operation, the bottom temperature is high, heat is transferred outwards, the drilling fluid in the annular space is heated and pressed, the pressed volume of an additive in the drilling fluid is reduced, the pressure bearing capacity of the drilling fluid is increased, and the stability of a shaft is guaranteed.
Detailed Description
The technical scheme of the invention is further explained by combining specific examples.
Examples
A compressible drilling fluid comprises bentonite slurry, a treating agent, a drilling fluid additive, a flow pattern regulator, a temperature-resistant and salt-resistant filtrate reducer, a hydrate inhibitor, a pH regulator and water.
In a preferred embodiment, the compressive drilling fluid comprises 1-4% of bentonite slurry, 0.3% of a treating agent, 2% of a drilling fluid additive, 3% of a flow pattern modifier, 3% of a temperature and salt resistant fluid loss additive and about 20% of a pH modifier by volume percentage.
In a preferred embodiment, the main mineral component of bentonite is montmorillonite, with a content of 85% to 90%. The drilling fluid is suspended in water, and one ton of high-quality bentonite can be used for preparing the drilling fluid with the viscosity of 16 mPa & s 3 。
In a preferred embodiment, the treating agent is polyacrylamide potassium salt (K-PAM), the substance is white or faint yellow powder, is easy to dissolve in water and absorb moisture, has low specific gravity and good heat resistance, has strong capability of inhibiting the dispersion of clay and drill cuttings, good temperature resistance and salt resistance and certain fluid loss reduction capability, can effectively coat the drill cuttings, controls formation slurry making, has good anti-collapse effect, and is beneficial to the protection and discovery of oil-gas layers.
In a preferred embodiment, the drilling fluid additive is a hollow spherical particle containing a gas therein and being insoluble in water. Has good fluidity, high temperature resistance, good thermal stability and easy compression in the operation process. When the pressure increases, the internal gas is exhausted and the particles are reduced. The drilling fluid additive comprises 50-65% of silicon dioxide, 6-8% of aluminum oxide, 15-20% of sodium oxide, 5-10% of potassium oxide and 3-5% of barite and limestone in percentage by mass. The preparation method comprises the following steps: crushing and mixing the substances, drying at high temperature, adding rubber powder, grinding into millimeter-sized particles by a ball mill, performing high-temperature melting at the temperature of more than 1000 ℃ after puffing, and finally cooling to obtain the additive.
In a preferred embodiment, the flow pattern modifier can be classified into positive charged colloid MMH and polyacrylamide PAM, depending on the formation and the effect. The positive charged colloid MMH is powdery, can improve the rheological property of the slurry, improve the viscosity of the slurry at low speed, enhance the suspension and slag carrying capacity of the slurry, reduce the precipitation probability of drilling slag in holes, reduce the abrasion of drilling tools and is suitable for a gravel layer and a rock layer. The polyacrylamide PAM is powdery, is used for flocculating and precipitating larger-particle drilling slag in the mud purification process to achieve the purpose of primary purification, is usually added into the mud by 0.2-0.5 percent to enhance the slag carrying capacity of the mud, and is suitable for clay layers, sand layers, gravel layers and gravel layers.
In a preferred embodiment, the salt-resistant temperature-resistant fluid loss additive is KFH-1, and the product can effectively reduce the high-temperature high-pressure fluid loss of the drilling fluid. The sodium sulfonate group is introduced, so that the hydration effect is strong, the bond energy of the associated water is high, the water solubility is enhanced, and the sodium sulfonate group plays an important role in consolidating the well wall and preventing collapse.
In a preferred embodiment, the hydrate inhibitor is prepared by compounding sodium chloride and acetic acid, and can better inhibit the generation of the hydrate when 0.25% of NaCl and 0.25% of acetic acid are added.
In a preferred embodiment, the pH modifier is potassium hydroxide and/or calcium hydroxide, which is effective to control the pH of the drilling fluid to maintain it within a suitable range.
In the present invention, the preparation method of the compression type drilling fluid according to the above technical scheme preferably includes the following steps: adding water into a liquid preparation tank truck by using a water injection pump, adjusting the rotating speed, adding sodium carbonate, slowly adding bentonite after the bentonite is completely dissolved, fully stirring to obtain base slurry, and adding a treating agent, a drilling fluid additive, a flow pattern regulator, a temperature-resistant and salt-resistant filtrate reducer and a hydrate inhibitor during stirring.
The preparation method comprises the following specific steps:
the method comprises the following steps: adding quantitative water into a liquid preparation tank vehicle by using a water injection pump;
step two: regulating the rotating speed, adding soda ash, and slowly adding bentonite after all the soda ash is dissolved;
step three: and sequentially adding a treating agent, a drilling fluid additive, a flow pattern regulator, a temperature-resistant and salt-resistant filtrate reducer and a hydrate inhibitor. The drilling fluid Ph is adjusted to the appropriate range.
Step four: the liquid preparation tank truck is connected with the injection pump by a tee joint and a pipeline, the outlet end of the tee joint is connected with the operation annulus, and the prepared drilling fluid is uniformly and continuously injected after the testing pressure of the pipeline meets the specification.
The drilling fluid in the embodiment has stable performance, good rheological property and certain compressibility.
TABLE 1
Table 1 shows the rheological property test results of the compression drilling fluid and the deepwater conventional deepwater drilling fluid at different temperatures, and it can be seen from table 1 that the drilling fluid prepared by the present invention still has good rheological properties after the addition of the novel additive.
To verify the compressibility of the drilling fluid, experiments were performed on a well in the south sea, with the results shown in table 2.
TABLE 2
As can be seen from Table 2, compared with the compression type drilling fluid and the conventional drilling fluid, the temperature near the mud line is basically kept unchanged, but the annulus backlog is obviously smaller than that of the conventional drilling fluid, which indicates that the drilling fluid has compressibility, the annulus backlog can be reduced to a certain extent by using the compression type drilling fluid, the pressure of the annulus wall is reduced, and the integrity of the shaft is guaranteed.
The invention being thus described by way of example, it will be understood that any simple alterations, modifications or other equivalent alterations which would be apparent to those skilled in the art without having the benefit of the teachings herein are deemed to fall within the scope and ambit of the present invention.
Claims (10)
1. A compressible drilling fluid, comprising: the used raw materials comprise: bentonite slurry, a treating agent, a drilling fluid additive, a flow pattern regulator, a temperature-resistant and salt-resistant filtrate reducer, a hydrate inhibitor, a pH regulator and water.
2. A compressible drilling fluid as claimed in claim 1, wherein: the drilling fluid comprises, by volume, 1-4% of bentonite slurry, 0.3% of a treating agent, 2% of a drilling fluid additive, 3% of a flow pattern regulator, 3% of a temperature-resistant and salt-resistant filtrate reducer, 0.01-6% of a hydrate inhibitor, 20% of a pH regulator and the balance of water.
3. A compressible drilling fluid as claimed in claim 2, wherein: the bentonite slurry contains 85-90% of montmorillonite by mass percent.
4. A compressible drilling fluid as claimed in claim 2, wherein: the treating agent is hydrolyzed potassium polyacrylamide (K-PAM).
5. A compressible drilling fluid according to claim 2, wherein: the drilling fluid additive comprises 50-65% of silicon dioxide, 6-8% of aluminum oxide, 15-20% of sodium oxide, 5-10% of potassium oxide, 2-3% of barite and 1-2% of limestone by mass percent; the preparation method comprises the following steps: crushing and mixing the substances, drying at high temperature, adding rubber powder, grinding the rubber powder into millimeter-sized particles through a ball mill, performing high-temperature melting at the temperature of more than 1000 ℃ after swelling, and finally cooling to obtain the additive, wherein the addition mass of the rubber powder is 35-60% of that of the flow pattern regulator.
6. A compressible drilling fluid as claimed in claim 2, wherein: the flow pattern modifier comprises positive charged colloid MMH and polyacrylamide PAM.
7. A compressible drilling fluid according to claim 2, wherein: the temperature-resistant and salt-resistant filtrate reducer KFH-1.
8. A compressible drilling fluid as claimed in claim 2, wherein: the hydrate inhibitor is obtained by compounding sodium chloride and acetic acid.
9. A compressible drilling fluid as claimed in claim 2, wherein: the pH regulator is potassium hydroxide and/or calcium hydroxide.
10. The preparation method of the compressive drilling fluid is characterized by comprising the following steps of: adding water into a liquid preparation tank truck by using a water injection pump, adding 1-4% of bentonite slurry, 0.3% of treating agent, 2% of drilling fluid additive, 3% of flow pattern regulator, 3% of temperature-resistant and salt-resistant filtrate reducer, 0.01-6% of hydrate inhibitor, 20% of pH regulator and the balance of water into the water according to volume percentage, and mixing to obtain the compressible drilling fluid.
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| Application Number | Priority Date | Filing Date | Title |
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| CN202111495661.2A CN115093840A (en) | 2021-12-08 | 2021-12-08 | Compressible drilling fluid and preparation method thereof |
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| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202111495661.2A CN115093840A (en) | 2021-12-08 | 2021-12-08 | Compressible drilling fluid and preparation method thereof |
Publications (1)
| Publication Number | Publication Date |
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| CN115093840A true CN115093840A (en) | 2022-09-23 |
Family
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| CN202111495661.2A Pending CN115093840A (en) | 2021-12-08 | 2021-12-08 | Compressible drilling fluid and preparation method thereof |
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Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN1977026A (en) * | 2004-06-17 | 2007-06-06 | 埃克森美孚上游研究公司 | Variable density drilling mud |
| CN103003519A (en) * | 2010-05-28 | 2013-03-27 | 康纳科菲利普斯公司 | Enhanced smear effect fracture plugging process for drilling systems |
| CN104194045A (en) * | 2014-07-24 | 2014-12-10 | 北京化工大学 | Method for preparing polymer composite material by expanded perlite |
| CN110144195A (en) * | 2019-05-20 | 2019-08-20 | 黄广展 | A kind of closure anti-sloughing agent and preparation method thereof |
| CN111518527A (en) * | 2019-10-12 | 2020-08-11 | 华南理工大学 | Elastic agent, preparation method thereof and casing expansion damage prevention elastic spacer fluid for well cementation |
-
2021
- 2021-12-08 CN CN202111495661.2A patent/CN115093840A/en active Pending
Patent Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN1977026A (en) * | 2004-06-17 | 2007-06-06 | 埃克森美孚上游研究公司 | Variable density drilling mud |
| CN103003519A (en) * | 2010-05-28 | 2013-03-27 | 康纳科菲利普斯公司 | Enhanced smear effect fracture plugging process for drilling systems |
| CN104194045A (en) * | 2014-07-24 | 2014-12-10 | 北京化工大学 | Method for preparing polymer composite material by expanded perlite |
| CN110144195A (en) * | 2019-05-20 | 2019-08-20 | 黄广展 | A kind of closure anti-sloughing agent and preparation method thereof |
| CN111518527A (en) * | 2019-10-12 | 2020-08-11 | 华南理工大学 | Elastic agent, preparation method thereof and casing expansion damage prevention elastic spacer fluid for well cementation |
Non-Patent Citations (1)
| Title |
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| 郭永宾等: "深水油气井环空带压预防弹性隔离液体系", 钻井液与完井液 * |
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Application publication date: 20220923 |