CN116496765A - Borehole wall reinforcing agent, and preparation method and application thereof - Google Patents
Borehole wall reinforcing agent, and preparation method and application thereof Download PDFInfo
- Publication number
- CN116496765A CN116496765A CN202310428180.2A CN202310428180A CN116496765A CN 116496765 A CN116496765 A CN 116496765A CN 202310428180 A CN202310428180 A CN 202310428180A CN 116496765 A CN116496765 A CN 116496765A
- Authority
- CN
- China
- Prior art keywords
- borehole wall
- enhancer
- amino
- silicon dioxide
- mass
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Pending
Links
- 238000002360 preparation method Methods 0.000 title abstract description 13
- 239000012744 reinforcing agent Substances 0.000 title description 27
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims abstract description 114
- 239000012530 fluid Substances 0.000 claims abstract description 40
- 238000005553 drilling Methods 0.000 claims abstract description 39
- 239000000377 silicon dioxide Substances 0.000 claims abstract description 37
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 36
- 239000002245 particle Substances 0.000 claims abstract description 35
- 238000005728 strengthening Methods 0.000 claims abstract description 31
- -1 amino modified silicon dioxide Chemical class 0.000 claims abstract description 27
- 230000005496 eutectics Effects 0.000 claims abstract description 27
- 239000002904 solvent Substances 0.000 claims abstract description 26
- 235000012239 silicon dioxide Nutrition 0.000 claims abstract description 7
- 239000003623 enhancer Substances 0.000 claims description 137
- 239000001257 hydrogen Substances 0.000 claims description 39
- 229910052739 hydrogen Inorganic materials 0.000 claims description 39
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 claims description 24
- 239000000243 solution Substances 0.000 claims description 19
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 17
- 238000000034 method Methods 0.000 claims description 16
- 239000004721 Polyphenylene oxide Substances 0.000 claims description 13
- 229920000570 polyether Polymers 0.000 claims description 13
- VHUUQVKOLVNVRT-UHFFFAOYSA-N Ammonium hydroxide Chemical compound [NH4+].[OH-] VHUUQVKOLVNVRT-UHFFFAOYSA-N 0.000 claims description 12
- 235000011114 ammonium hydroxide Nutrition 0.000 claims description 12
- 238000001035 drying Methods 0.000 claims description 12
- 238000002156 mixing Methods 0.000 claims description 11
- 239000004372 Polyvinyl alcohol Substances 0.000 claims description 10
- 238000001354 calcination Methods 0.000 claims description 10
- 238000010335 hydrothermal treatment Methods 0.000 claims description 10
- 229920002451 polyvinyl alcohol Polymers 0.000 claims description 10
- 238000005406 washing Methods 0.000 claims description 10
- 239000001763 2-hydroxyethyl(trimethyl)azanium Substances 0.000 claims description 9
- 235000019743 Choline chloride Nutrition 0.000 claims description 9
- PEDCQBHIVMGVHV-UHFFFAOYSA-N Glycerine Chemical compound OCC(O)CO PEDCQBHIVMGVHV-UHFFFAOYSA-N 0.000 claims description 9
- 229960003178 choline chloride Drugs 0.000 claims description 9
- SGMZJAMFUVOLNK-UHFFFAOYSA-M choline chloride Chemical compound [Cl-].C[N+](C)(C)CCO SGMZJAMFUVOLNK-UHFFFAOYSA-M 0.000 claims description 9
- QTBSBXVTEAMEQO-UHFFFAOYSA-N Acetic acid Chemical compound CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 claims description 8
- XBDQKXXYIPTUBI-UHFFFAOYSA-N dimethylselenoniopropionate Natural products CCC(O)=O XBDQKXXYIPTUBI-UHFFFAOYSA-N 0.000 claims description 6
- BDAGIHXWWSANSR-UHFFFAOYSA-N methanoic acid Natural products OC=O BDAGIHXWWSANSR-UHFFFAOYSA-N 0.000 claims description 6
- 230000008569 process Effects 0.000 claims description 6
- 239000002202 Polyethylene glycol Substances 0.000 claims description 5
- 229920001223 polyethylene glycol Polymers 0.000 claims description 5
- 239000007787 solid Substances 0.000 claims description 5
- BPQQTUXANYXVAA-UHFFFAOYSA-N Orthosilicate Chemical compound [O-][Si]([O-])([O-])[O-] BPQQTUXANYXVAA-UHFFFAOYSA-N 0.000 claims description 4
- 238000002791 soaking Methods 0.000 claims description 4
- OSWFIVFLDKOXQC-UHFFFAOYSA-N 4-(3-methoxyphenyl)aniline Chemical compound COC1=CC=CC(C=2C=CC(N)=CC=2)=C1 OSWFIVFLDKOXQC-UHFFFAOYSA-N 0.000 claims description 3
- WQZGKKKJIJFFOK-GASJEMHNSA-N Glucose Natural products OC[C@H]1OC(O)[C@H](O)[C@@H](O)[C@@H]1O WQZGKKKJIJFFOK-GASJEMHNSA-N 0.000 claims description 3
- 235000011054 acetic acid Nutrition 0.000 claims description 3
- CDQSJQSWAWPGKG-UHFFFAOYSA-N butane-1,1-diol Chemical compound CCCC(O)O CDQSJQSWAWPGKG-UHFFFAOYSA-N 0.000 claims description 3
- 235000019253 formic acid Nutrition 0.000 claims description 3
- 239000008103 glucose Substances 0.000 claims description 3
- 235000019260 propionic acid Nutrition 0.000 claims description 3
- IUVKMZGDUIUOCP-BTNSXGMBSA-N quinbolone Chemical compound O([C@H]1CC[C@H]2[C@H]3[C@@H]([C@]4(C=CC(=O)C=C4CC3)C)CC[C@@]21C)C1=CCCC1 IUVKMZGDUIUOCP-BTNSXGMBSA-N 0.000 claims description 3
- 125000003277 amino group Chemical group 0.000 claims description 2
- WQZGKKKJIJFFOK-VFUOTHLCSA-N beta-D-glucose Chemical compound OC[C@H]1O[C@@H](O)[C@H](O)[C@@H](O)[C@@H]1O WQZGKKKJIJFFOK-VFUOTHLCSA-N 0.000 claims description 2
- 239000007788 liquid Substances 0.000 claims description 2
- 238000002715 modification method Methods 0.000 claims description 2
- 125000002924 primary amino group Chemical group [H]N([H])* 0.000 claims description 2
- 238000000926 separation method Methods 0.000 claims description 2
- 150000001735 carboxylic acids Chemical class 0.000 claims 2
- 239000011148 porous material Substances 0.000 abstract description 5
- 230000005540 biological transmission Effects 0.000 abstract description 4
- 230000035699 permeability Effects 0.000 abstract description 4
- 238000004132 cross linking Methods 0.000 abstract description 3
- 230000035945 sensitivity Effects 0.000 abstract description 3
- 239000000126 substance Substances 0.000 abstract description 3
- 230000001934 delay Effects 0.000 abstract 1
- 230000000052 comparative effect Effects 0.000 description 21
- 239000002002 slurry Substances 0.000 description 14
- 239000000370 acceptor Substances 0.000 description 13
- 238000012360 testing method Methods 0.000 description 10
- BOTDANWDWHJENH-UHFFFAOYSA-N Tetraethyl orthosilicate Chemical group CCO[Si](OCC)(OCC)OCC BOTDANWDWHJENH-UHFFFAOYSA-N 0.000 description 6
- 239000007789 gas Substances 0.000 description 6
- 239000000203 mixture Substances 0.000 description 6
- 230000000694 effects Effects 0.000 description 5
- 238000011049 filling Methods 0.000 description 5
- 239000004576 sand Substances 0.000 description 5
- 238000003756 stirring Methods 0.000 description 5
- 238000011282 treatment Methods 0.000 description 5
- 235000001014 amino acid Nutrition 0.000 description 4
- 239000003995 emulsifying agent Substances 0.000 description 4
- 238000010438 heat treatment Methods 0.000 description 4
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 4
- 239000011259 mixed solution Substances 0.000 description 4
- 239000003921 oil Substances 0.000 description 4
- 238000001179 sorption measurement Methods 0.000 description 4
- 230000000087 stabilizing effect Effects 0.000 description 4
- 150000001413 amino acids Chemical class 0.000 description 3
- 230000015572 biosynthetic process Effects 0.000 description 3
- 230000000903 blocking effect Effects 0.000 description 3
- 239000000084 colloidal system Substances 0.000 description 3
- 239000000706 filtrate Substances 0.000 description 3
- 238000005755 formation reaction Methods 0.000 description 3
- 239000002086 nanomaterial Substances 0.000 description 3
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 2
- WHUUTDBJXJRKMK-UHFFFAOYSA-N Glutamic acid Natural products OC(=O)C(N)CCC(O)=O WHUUTDBJXJRKMK-UHFFFAOYSA-N 0.000 description 2
- 230000009471 action Effects 0.000 description 2
- 230000032683 aging Effects 0.000 description 2
- 150000001732 carboxylic acid derivatives Chemical class 0.000 description 2
- 238000006243 chemical reaction Methods 0.000 description 2
- 230000008014 freezing Effects 0.000 description 2
- 238000007710 freezing Methods 0.000 description 2
- 235000013922 glutamic acid Nutrition 0.000 description 2
- 239000004220 glutamic acid Substances 0.000 description 2
- 230000009545 invasion Effects 0.000 description 2
- 238000012423 maintenance Methods 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 239000003345 natural gas Substances 0.000 description 2
- 239000003209 petroleum derivative Substances 0.000 description 2
- WLJVXDMOQOGPHL-UHFFFAOYSA-N phenylacetic acid Chemical group OC(=O)CC1=CC=CC=C1 WLJVXDMOQOGPHL-UHFFFAOYSA-N 0.000 description 2
- 229920001343 polytetrafluoroethylene Polymers 0.000 description 2
- 239000004810 polytetrafluoroethylene Substances 0.000 description 2
- 230000003405 preventing effect Effects 0.000 description 2
- 239000011435 rock Substances 0.000 description 2
- 238000007789 sealing Methods 0.000 description 2
- 230000000007 visual effect Effects 0.000 description 2
- 239000000080 wetting agent Substances 0.000 description 2
- WQPMYSHJKXVTME-UHFFFAOYSA-N 3-hydroxypropane-1-sulfonic acid Chemical compound OCCCS(O)(=O)=O WQPMYSHJKXVTME-UHFFFAOYSA-N 0.000 description 1
- QGZKDVFQNNGYKY-UHFFFAOYSA-N Ammonia Chemical compound N QGZKDVFQNNGYKY-UHFFFAOYSA-N 0.000 description 1
- QGTHRCDTVFFPBQ-UHFFFAOYSA-N C(C(=C)C)(=O)OCCCO.[Na] Chemical group C(C(=C)C)(=O)OCCCO.[Na] QGTHRCDTVFFPBQ-UHFFFAOYSA-N 0.000 description 1
- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 description 1
- ZAMOUSCENKQFHK-UHFFFAOYSA-N Chlorine atom Chemical compound [Cl] ZAMOUSCENKQFHK-UHFFFAOYSA-N 0.000 description 1
- DGAQECJNVWCQMB-PUAWFVPOSA-M Ilexoside XXIX Chemical group C[C@@H]1CC[C@@]2(CC[C@@]3(C(=CC[C@H]4[C@]3(CC[C@@H]5[C@@]4(CC[C@@H](C5(C)C)OS(=O)(=O)[O-])C)C)[C@@H]2[C@]1(C)O)C)C(=O)O[C@H]6[C@@H]([C@H]([C@@H]([C@H](O6)CO)O)O)O.[Na+] DGAQECJNVWCQMB-PUAWFVPOSA-M 0.000 description 1
- OKIZCWYLBDKLSU-UHFFFAOYSA-M N,N,N-Trimethylmethanaminium chloride Chemical compound [Cl-].C[N+](C)(C)C OKIZCWYLBDKLSU-UHFFFAOYSA-M 0.000 description 1
- IGFHQQFPSIBGKE-UHFFFAOYSA-N Nonylphenol Natural products CCCCCCCCCC1=CC=C(O)C=C1 IGFHQQFPSIBGKE-UHFFFAOYSA-N 0.000 description 1
- 125000000218 acetic acid group Chemical group C(C)(=O)* 0.000 description 1
- 239000008186 active pharmaceutical agent Substances 0.000 description 1
- 125000005336 allyloxy group Chemical group 0.000 description 1
- 239000007864 aqueous solution Substances 0.000 description 1
- 239000010426 asphalt Substances 0.000 description 1
- TZCXTZWJZNENPQ-UHFFFAOYSA-L barium sulfate Chemical compound [Ba+2].[O-]S([O-])(=O)=O TZCXTZWJZNENPQ-UHFFFAOYSA-L 0.000 description 1
- 239000010428 baryte Substances 0.000 description 1
- 229910052601 baryte Inorganic materials 0.000 description 1
- 239000000440 bentonite Substances 0.000 description 1
- 229910000278 bentonite Inorganic materials 0.000 description 1
- SVPXDRXYRYOSEX-UHFFFAOYSA-N bentoquatam Chemical compound O.O=[Si]=O.O=[Al]O[Al]=O SVPXDRXYRYOSEX-UHFFFAOYSA-N 0.000 description 1
- 239000001110 calcium chloride Substances 0.000 description 1
- 229910001628 calcium chloride Inorganic materials 0.000 description 1
- BRPQOXSCLDDYGP-UHFFFAOYSA-N calcium oxide Chemical group [O-2].[Ca+2] BRPQOXSCLDDYGP-UHFFFAOYSA-N 0.000 description 1
- 239000000292 calcium oxide Substances 0.000 description 1
- ODINCKMPIJJUCX-UHFFFAOYSA-N calcium oxide Inorganic materials [Ca]=O ODINCKMPIJJUCX-UHFFFAOYSA-N 0.000 description 1
- 125000003178 carboxy group Chemical group [H]OC(*)=O 0.000 description 1
- 239000003054 catalyst Substances 0.000 description 1
- 239000003638 chemical reducing agent Substances 0.000 description 1
- 239000000460 chlorine Substances 0.000 description 1
- 229910052801 chlorine Inorganic materials 0.000 description 1
- 229960001231 choline Drugs 0.000 description 1
- OEYIOHPDSNJKLS-UHFFFAOYSA-N choline Chemical compound C[N+](C)(C)CCO OEYIOHPDSNJKLS-UHFFFAOYSA-N 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 239000008367 deionised water Substances 0.000 description 1
- 229910021641 deionized water Inorganic materials 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000018109 developmental process Effects 0.000 description 1
- 239000002283 diesel fuel Substances 0.000 description 1
- 239000006185 dispersion Substances 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
- 239000000839 emulsion Substances 0.000 description 1
- 238000001914 filtration Methods 0.000 description 1
- 239000003292 glue Substances 0.000 description 1
- 125000002887 hydroxy group Chemical group [H]O* 0.000 description 1
- 238000007654 immersion Methods 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000012046 mixed solvent Substances 0.000 description 1
- 239000002105 nanoparticle Substances 0.000 description 1
- 230000007935 neutral effect Effects 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
- 229960003424 phenylacetic acid Drugs 0.000 description 1
- 239000003279 phenylacetic acid Substances 0.000 description 1
- 229920000056 polyoxyethylene ether Polymers 0.000 description 1
- 229940051841 polyoxyethylene ether Drugs 0.000 description 1
- 239000000843 powder Substances 0.000 description 1
- 238000004321 preservation Methods 0.000 description 1
- 239000000047 product Substances 0.000 description 1
- 239000011734 sodium Substances 0.000 description 1
- 229910052708 sodium Inorganic materials 0.000 description 1
- 239000002689 soil Substances 0.000 description 1
- 238000003892 spreading Methods 0.000 description 1
- 230000007480 spreading Effects 0.000 description 1
- 230000006641 stabilisation Effects 0.000 description 1
- 238000011105 stabilization Methods 0.000 description 1
- 238000010998 test method Methods 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
- C09K8/03—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
- C09K8/02—Well-drilling compositions
- C09K8/32—Non-aqueous well-drilling compositions, e.g. oil-based
- C09K8/36—Water-in-oil emulsions
-
- 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
Landscapes
- 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)
- Oil, Petroleum & Natural Gas (AREA)
- Compounds Of Alkaline-Earth Elements, Aluminum Or Rare-Earth Metals (AREA)
Abstract
The invention relates to a well wall strengthening agent, a preparation method and application thereof, and belongs to the technical field of oilfield chemicals. The well wall strengthening agent is mainly prepared from amino modified silicon dioxide and eutectic solvent, has good rheological property, high temperature resistance and compatibility with a drilling fluid system, can improve the well wall adhesiveness of silicon dioxide particles after micro-crosslinking of the amino modified silicon dioxide and the eutectic solvent, reduces pressure sensitivity, enhances the dispersibility and lubricity of the amino modified silicon dioxide and the eutectic solvent in the drilling fluid system, can form a deformable outer plugging layer, reduces the permeability of a shale stratum, delays pore pressure transmission, improves the bearing capacity of the stratum and strengthens the stability of the well wall.
Description
Technical Field
The invention relates to a well wall strengthening agent, a preparation method and application thereof, and belongs to the technical field of oilfield chemicals.
Background
With the large-scale development of unconventional gas reservoirs taking shale gas as a sign at home and abroad, the problem of well instability of complex stratum is increasingly outstanding. However, the borehole instability of the stratum mainly occurs in the hard and brittle shale stratum containing cracks, and the stratum mostly has closed or open stratums and microcracks, so that the acting force of a capillary is strong. Under the action of positive pressure difference and capillary pressure, drilling fluid filtrate is easy to invade, so that shale is cracked along a crack surface or a bedding surface and continuously develops to depth along the crack, thereby causing a well wall instability phenomenon, and collapse and drill sticking are caused when serious. Therefore, the cracks are filled, and a blocking layer is formed on the well wall, so that the pressure transmission process caused by invasion of the well bore fluid into the stratum can be effectively prevented, and the purpose of stabilizing the well wall is achieved.
The well wall reinforcing agent is adopted, and the purpose of stabilizing the well wall can be achieved by filling cracks and forming a blocking layer on the well wall to effectively prevent the pressure transmission process caused by the invasion of well fluid into the stratum. Shale is the rock type with the smallest pore size of all formation rocks, with pore sizes less than 1 μm, making it difficult for conventional treatments in drilling fluids to form mud cakes in shale formations. Therefore, for the last-stage plugging material for stabilizing the well wall of the shale stratum, the grain size of the last-stage plugging material must be in a nano level to prevent filtrate from entering the stratum, so that the effect of stabilizing the well wall is achieved. Because the conventional drilling fluid plugging agent has larger particle size, and is matched with bentonite, barite and other drilling fluid treatment agents, the efficient plugging anti-collapse drilling fluid with uniform particle size distribution is difficult to form, mud cakes with permeability approaching zero are difficult to form, the stratum bearing capacity is improved, and collapse and block falling in the drilling process are avoided. Although the nano material has extremely small particle size, can enter the nano hole gap in theory and can be bridged and blocked at the port, the dispersion stability is poor, the nano material is easy to agglomerate into blocks and is not easy to discharge; secondly, the adhesiveness of the well wall is weaker, and the blocking performance of the well wall is affected. In the traditional plugging and collapse preventing process, plugging is carried out by accumulating plugging agents with different particle diameters, the pressure sensitivity characteristic still exists, and the plugging agent is not easy to stay in the pores, so that the effective filling of nano particles in the gaps can not be realized, and the plugging performance is poor. In addition, gaps still exist in the plugging process of the single-phase nano material, so that the bearing capacity, the toughness and the well wall adhesiveness are poor.
Disclosure of Invention
The invention aims to provide a well wall reinforcing agent, which can solve the problem that the existing well wall reinforcing agent has poor bearing capacity.
The second object of the invention is to provide a method for preparing the well wall strengthening agent.
A third object of the present invention is to provide a use of a borehole wall enhancer in drilling fluids.
In order to achieve the above purpose, the technical scheme adopted by the well wall reinforcing agent of the invention is as follows:
a well wall strengthening agent is prepared from amino modified silicon dioxide and eutectic solvent including hydrogen bond donor and hydrogen bond acceptor, wherein the hydrogen bond donor is C 1 ～C 5 One or any combination of carboxylic acid, phenylacetic acid, amino acid, glycerol, polyethylene glycol, glucose and butanediol, wherein the hydrogen bond acceptor comprises choline chloride, and the mass ratio of the hydrogen bond donor to the hydrogen bond acceptor is (1-16): 1; the mass of the amino modified silica and chlorine in the eutectic solventThe mass ratio of the choline is (0.01-0.1): 1.
The well wall strengthening agent is mainly prepared from amino modified silicon dioxide and eutectic solvent, has good rheological property, high temperature resistance and compatibility with a drilling fluid system, and can improve the well wall adhesion of silicon dioxide particles, reduce pressure sensitivity, enhance the dispersibility and lubricity of the amino modified silicon dioxide and the eutectic solvent in the drilling fluid system, form a deformable external plugging layer, reduce the permeability of shale stratum, delay pore pressure transmission, improve the stratum bearing capacity and strengthen the well wall stability after micro-crosslinking of the amino modified silicon dioxide and the eutectic solvent (the carboxyl or hydroxyl in the silicon dioxide and the eutectic solvent are subjected to adsorption, hydrogen bonding and other actions).
The well wall reinforcing agent is colloid at room temperature, and can be solidified at high temperature to form solid (colloid with certain strength), so that the well wall can be adhered in a solid form at a higher temperature of a stratum. The well wall strengthening agent can be used in a wider temperature range, and when the eutectic solvent composition is changed, the using temperature range of the well wall strengthening agent is 20-150 ℃, namely the temperature range of forming solid (colloid with certain strength) is 20-150 ℃.
Preferably, the C 1 ～C 5 The carboxylic acid is selected from one or any combination of formic acid, acetic acid and propionic acid.
Preferably, the polyethylene glycol has a weight average molecular weight of 200 to 900. For example, the polyethylene glycol has a weight average molecular weight of 800.
Preferably, the amino acid is glutamic acid.
The different types, chemical compositions and amounts of hydrogen bond acceptors can result in different freezing points of the resulting eutectic solvents, which preferably have a freezing point of 20-150 ℃ for better versatility of the borehole wall enhancer of the invention.
In the present invention, the amino-modified silica may be obtained commercially or may be prepared by itself. Preferably, the amino-modified silica is prepared from silica modified with an amino group; the amino modification method comprises the following steps: soaking the silicon dioxide with the average particle size of 20-500 nm in ammonia water, washing and drying to obtain the amino modified silicon dioxide.
Preferably, the volume of ammonia water per 5g of silica having an average particle diameter of 20 to 500nm is 20 to 60mL.
Preferably, the concentration of the ammonia water is 5-10 mol/L.
Preferably, the soaking time is not less than 3 hours.
Preferably, the washing is washing the soaked system to neutrality. Preferably, the drying temperature is 25-60 ℃ and the drying time is 6-12 h. For example, the drying temperature is 40 ℃ and the time is 8 hours.
Preferably, the silica having an average particle diameter of 20 to 500nm is produced by a method comprising the steps of: uniformly mixing a polyether solution, water, hydrochloric acid and a polyvinyl alcohol solution, adding tetraalkyl orthosilicate, mixing and reacting for at least 10min, standing the mixed and reacted system for at least 12h, mixing the standing system for at least 12h, carrying out hydrothermal treatment on the mixed system, carrying out solid-liquid separation, washing, drying, and calcining the dried solid to obtain the silicon dioxide with the average particle size of 20-500 nm. Preferably, the temperature of the rest employed in the preparation of the silica is not less than 26 ℃. Preferably, the temperature of the mixing reaction is not lower than 37 ℃. Preferably, the temperature at which the system after standing is mixed is not lower than 35 ℃.
Preferably, the tetraalkyl orthosilicate is tetraethyl orthosilicate.
Preferably, the mass fraction of the polyether solution is 5-40%. For example, the polyether solution has a mass fraction of 10%. Preferably, the mass of polyether solution employed per 40mL of water is 10-50 g.
Preferably, the mass fraction of the polyvinyl alcohol solution is 5-10%. For example, the polyvinyl alcohol solution has a mass fraction of 8%. Preferably, the weight average molecular weight of the polyvinyl alcohol is 2.5 to 3.5 ten thousand. Preferably, the mass of the polyvinyl alcohol solution used per 40mL of water is 50 to 70g. For example, the mass of the polyvinyl alcohol solution used per 40mL of water is 60g.
Hydrochloric acid is used as a catalyst, and preferably the mass fraction of the hydrochloric acid is 10-37%. Preferably, the volume of hydrochloric acid employed per 40mL of water is 5-15 mL.
The amount of tetraethyl orthosilicate used will affect the size of the silica particles, preferably 3 to 6g of tetraalkyl orthosilicate per 40mL of water.
Preferably, the hydrothermal treatment is performed in a closed environment. Preferably, the temperature of the hydrothermal treatment is 80-120 ℃ and the time is 12-36 h.
Preferably, the calcination temperature is 500-600 ℃ and the time is 3-6 h.
The technical scheme adopted by the preparation method of the well wall reinforcing agent is as follows:
the preparation method of the well wall reinforcing agent comprises the following steps: and uniformly mixing the amino modified silicon dioxide with the formula amount and the eutectic solvent to obtain the well wall strengthening agent.
The preparation method of the well wall reinforcing agent has the advantages of simple process, no pollution to the environment and low cost, the prepared well wall reinforcing agent can be uniformly dispersed in drilling fluid, the rheological property, pressure resistance and the like of the drilling fluid can be improved, micro-nano cracks of the well wall can be effectively plugged through adsorption and deformation filling effects, the stability of the well wall is kept, the problem of drilling fluid leakage of hard and brittle shale and shale oil-gas stratum can be effectively solved, and the preparation method has wide application prospect.
Preferably, the mixing method comprises the following steps: adding the amino modified silicon dioxide into the eutectic solvent, and then mixing for 1-3 hours. Preferably, the amino modified silica is added at a rate of no greater than 10mg/min. In order to ensure that the amino-modified silica is sufficiently involved in the micro-crosslinking reaction, the amino-modified silica needs to be slowly added to the eutectic solvent.
The technical scheme adopted by the application of the well wall reinforcing agent in the drilling fluid is as follows:
the use of a borehole wall enhancer as described above in a drilling fluid.
The well wall reinforcing agent can be uniformly dispersed in drilling fluid, can improve rheological property, pressure resistance and the like of the drilling fluid, can effectively block micro-nano cracks of the well wall through adsorption, deformation and filling effects, keeps the well wall stable, can effectively solve the problem of leakage of the drilling fluid of hard and brittle shale and shale oil-gas stratum, and has wide application prospect.
Drawings
FIG. 1 is a schematic flow chart of a method for preparing a borehole wall enhancer of the invention.
Detailed Description
The technical scheme of the invention is further described below with reference to specific embodiments.
1. Specific examples of the borehole wall strengthening agent of the present invention are as follows:
example 1
The well wall strengthening agent of the embodiment is prepared from amino-modified silicon dioxide and a eutectic solvent, wherein the eutectic solvent consists of a hydrogen bond donor and a hydrogen bond acceptor, the hydrogen bond donor is formic acid, the hydrogen bond acceptor is choline chloride, and the mass ratio of the hydrogen bond donor to the hydrogen bond acceptor is 3:1; the ratio of the mass of the amino-modified silicon dioxide to the mass of the choline chloride in the eutectic solvent is 0.05:1;
amino modified silica is prepared by a process comprising the steps of:
(1) Adding 20g of a polyether P123 solution with the mass fraction of 10% into a mixed solution prepared from 40mL of deionized water, 9mL of hydrochloric acid (with the mass fraction of 37%) and 60g of a polyvinyl alcohol (with the mass fraction of 8% and the weight average molecular weight of 2.5-3.5 ten thousand), placing the mixed solution in a constant-temperature magnetic stirrer at 37 ℃ for stirring for 1h, adding 4.4g of tetraethyl orthosilicate, continuing stirring for reacting for 10min, standing the reacted system at 26 ℃ for 12h, stirring the standing system at 35 ℃ for 12h, transferring the stirred system into a polytetrafluoroethylene bottle with the volume of 100mL, placing the polytetrafluoroethylene bottle into an autoclave, carrying out hydro-thermal treatment at 100 ℃ for 24h under sealing, centrifuging, washing and drying the hydro-thermal treated system, and calcining the dried white product at 550 ℃ for 4h to obtain silica with the average particle size of 80 nm;
(2) Spreading the silica prepared in the step (1) with the mass of 5g in a surface dish, then dropwise adding 50mL of ammonia water with the concentration of 10mol/L to ensure that the silica powder is fully contacted with the ammonia water, then placing the surface dish in an ammonia gas atmosphere for standing at constant temperature (room temperature), washing the standing system with clear water until a washing solution is neutral after standing for 3 hours, and then drying at 40 ℃ for 8 hours to obtain the amino modified silica.
Example 2
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica used in the borehole wall enhancer of this example was prepared such that the mass of the polyether P123 solution used in step (1) was 10g, and the average particle diameter of the prepared silica was 500nm.
Example 3
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica used in the borehole wall enhancer of this example was prepared such that the mass of the polyether P123 solution used in step (1) was 30g, and the average particle diameter of the prepared silica was 90nm.
Example 4
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica used in the borehole wall enhancer of this example was prepared such that the mass of the polyether P123 solution used in step (1) was 40g, and the average particle diameter of the prepared silica was 70nm.
Example 5
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica used in the borehole wall enhancer of this example was prepared such that the mass of the polyether P123 solution used in step (1) was 50g, and the average particle diameter of the prepared silica was 60nm.
Example 6
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica used in the borehole wall enhancer of this example was prepared by using 5mL of hydrochloric acid in the volume of step (1), and the average particle diameter of the prepared silica was 150nm.
Example 7
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica used in the borehole wall enhancer of this example was prepared by using 12mL of hydrochloric acid in the volume of step (1), and the average particle diameter of the prepared silica was 85nm.
Example 8
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica used in the borehole wall enhancer of this example was prepared by using 15mL of hydrochloric acid in the volume of step (1), and the average particle diameter of the prepared silica was 75nm.
Example 9
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica used in the borehole wall enhancer of this example was prepared by using tetraethyl orthosilicate having a mass of 3g in step (1), and the average particle diameter of the prepared silica was 100nm.
Example 10
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica used in the borehole wall enhancer of this example was prepared such that the mass of tetraethyl orthosilicate used in step (1) was 5g, and the average particle diameter of the prepared silica was 35nm.
Example 11
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica used in the borehole wall enhancer of this example was prepared such that the mass of tetraethyl orthosilicate used in step (1) was 6g, and the average particle diameter of the prepared silica was 20nm.
Example 12
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica used in the borehole wall enhancer of this example was prepared at a temperature of 80℃in the hydrothermal treatment of step (1), and the average particle diameter of the prepared silica was 30nm.
Example 13
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica used in the borehole wall enhancer of this example was prepared at a temperature of 120℃in the hydrothermal treatment of step (1), and the average particle diameter of the prepared silica was 62nm.
Example 14
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica used in the borehole wall enhancer of this example was prepared by performing the hydrothermal treatment in step (1) for 12 hours, and the average particle diameter of the prepared silica was 25nm.
Example 15
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica used in the borehole wall enhancer of this example was prepared by performing the hydrothermal treatment in step (1) for 36 hours, and the average particle diameter of the prepared silica was 49nm.
Example 16
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica used in the borehole wall enhancer of this example was prepared at a calcination temperature of 500℃in step (1), and the average particle diameter of the prepared silica was 80nm.
Example 17
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica used in the borehole wall enhancer of this example was prepared at a calcination temperature of 600℃in step (1), and the average particle diameter of the prepared silica was 80nm.
Example 18
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica used in the borehole wall enhancer of this example was prepared by calcining for 3 hours in step (1), and the average particle diameter of the prepared silica was 80nm.
Example 19
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica used in the borehole wall enhancer of this example was prepared by calcining for 6 hours in step (1), and the average particle diameter of the prepared silica was 80nm.
Example 20
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica used in the borehole wall enhancer of this example was prepared by using 20mL of ammonia water in the volume of 20mL in step (2).
Example 21
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica used in the borehole wall enhancer of this example was prepared with a volume of 40mL of ammonia water used in step (2).
Example 22
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica used in the borehole wall enhancer of this example was prepared by using 60mL of ammonia water in the volume of 60mL in step (2).
Example 23
The borehole wall enhancer of this example differs from the borehole wall enhancer of example 1 only in that the hydrogen bond donor used in the borehole wall enhancer of this example is acetic acid.
Example 24
The borehole wall enhancer of this example differs from the borehole wall enhancer of example 1 only in that the hydrogen bond donor used in the borehole wall enhancer of this example is propionic acid.
Example 25
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the hydrogen bond donor used in the borehole wall enhancer of this example was glycerol.
Example 26
The borehole wall strengthening agent of this example was different from the borehole wall strengthening agent of example 1 only in that the hydrogen bond donor used in the borehole wall strengthening agent of this example was polyethylene glycol (weight average molecular weight 800).
Example 27
The borehole wall enhancer of this example is different from the borehole wall enhancer of example 1 only in that the hydrogen bond donor used in the borehole wall enhancer of this example is phenylacetic acid.
Example 28
The borehole wall enhancer of this example is different from the borehole wall enhancer of example 1 only in that the hydrogen bond donor used in the borehole wall enhancer of this example is an amino acid (the amino acid is glutamic acid).
Example 29
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the hydrogen bond donor used in the borehole wall enhancer of this example was glucose.
Example 30
The borehole wall enhancer of this example is different from the borehole wall enhancer of example 1 only in that the hydrogen bond donor used in the borehole wall enhancer of this example is butanediol.
Example 31
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the ratio of the mass of the amino-modified silica used in the borehole wall enhancer of this example to the mass of choline chloride in the eutectic solvent was 0.01:1.
Example 32
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the ratio of the mass of the amino-modified silica used in the borehole wall enhancer of this example to the mass of choline chloride in the eutectic solvent was 0.1:1.
Example 33
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the mass ratio of the hydrogen bond donor to the hydrogen bond acceptor used in the borehole wall enhancer of this example was 1:1.
Example 34
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the mass ratio of the hydrogen bond donor to the hydrogen bond acceptor used in the borehole wall enhancer of this example was 8:1.
Example 35
The borehole wall enhancer of this example was different from the borehole wall enhancer of example 1 only in that the mass ratio of the hydrogen bond donor to the hydrogen bond acceptor used in the borehole wall enhancer of this example was 16:1.
Comparative example 1
The borehole wall strengthening agent of this comparative example was different from the borehole wall strengthening agent of example 1 only in that the mass ratio of the hydrogen bond donor and the hydrogen bond acceptor used in the borehole wall strengthening agent of this comparative example was 0.8:1.
Comparative example 2
The borehole wall strengthening agent of this comparative example was different from the borehole wall strengthening agent of example 1 only in that the mass ratio of the hydrogen bond donor and the hydrogen bond acceptor used in the borehole wall strengthening agent of this comparative example was 18:1.
Comparative example 3
The borehole wall enhancer of the present comparative example was different from the borehole wall enhancer of example 1 only in that the amino-modified silica was replaced with a silica having an average particle diameter of 80nm (the silica having an average particle diameter of 80nm produced in step 1 in the method for producing amino-modified silica in the borehole wall enhancer of example 1).
Comparative example 4
The borehole wall strengthening agent of this comparative example was different from the borehole wall strengthening agent of example 1 only in that the hydrogen bond acceptor used in the borehole wall strengthening agent of this comparative example was tetramethyl ammonium chloride.
Comparative example 5
The borehole wall enhancer of this comparative example was different from the borehole wall enhancer of example 1 only in that the ratio of the mass of the amino-modified silica in the borehole wall enhancer of this comparative example to the mass of the choline chloride in the eutectic solvent was 0.005:1.
Comparative example 6
The borehole wall enhancer of this comparative example was different from the borehole wall enhancer of example 1 only in that the ratio of the mass of the amino-modified silica in the borehole wall enhancer of this comparative example to the mass of the choline chloride in the eutectic solvent was 0.15:1.
The preparation method of the well wall reinforcing agent of the comparative examples 1-6 specifically comprises the following steps: adding amino modified silicon dioxide with the formula amount into the eutectic solvent at the speed of 10mg/min, fully stirring to obtain a mixture, and then placing the mixture into an oil bath pot at the temperature of 25 ℃ for heating treatment for 2 hours to obtain a mixed solution with certain viscosity, namely the well wall strengthening agent.
2. The specific examples of the preparation method of the well wall reinforcing agent of the invention are as follows:
the preparation method of the well wall reinforcing agent of the embodiments 1 to 35, as shown in fig. 1, specifically comprises the following steps: adding amino modified silicon dioxide with the formula amount into the eutectic solvent at the speed of 10mg/min, fully stirring to obtain a mixture, and then placing the mixture into an oil bath pot at the temperature of 25 ℃ for heating treatment for 2 hours to obtain a mixed solution with certain viscosity, namely the well wall strengthening agent.
3. Specific examples of applications of the borehole wall strengthening agent of the present invention in drilling fluids are as follows:
the borehole wall enhancers of examples 1-35 were used in drilling fluids.
Experimental example 1
To test the setting temperature of the borehole wall enhancers of examples 1-28, the borehole wall enhancers were placed in an aging tank, the aging tank was placed in a roller furnace (model GW 300) with a set heating temperature, fluidity of the borehole wall enhancers at different temperatures was observed and recorded, and a significant gel formation temperature range was recorded (only a partial temperature range test was selected), and the results are shown in Table 1.
TABLE 1 gel forming temperatures of borehole wall enhancers of examples 1-28
As can be seen from Table 1, the gel forming temperatures of the borehole wall enhancers of examples 1-28 were adjustable from 50 to 130 ℃. Corresponding well wall reinforcing agents can be selected according to actual temperatures of different well sections required on site. The well wall reinforcing agents of the embodiment 1, the embodiment 8 and the embodiment 28 can be quickly solidified into glue at the high temperature higher than 120 ℃ so as to meet temporary plugging at the medium and high temperature.
Experimental example 2
In order to evaluate the pressure-bearing strength of the well wall reinforcing agent, a certain amount of the well wall reinforcing agent is poured into a slurry cup, the total amount of the well wall reinforcing agent is lower than the scale mark of the slurry cup, the slurry cup is placed into a heating sleeve of a high-temperature high-pressure water loss instrument after a cup cover is fastened, the temperature is raised to a set temperature (maintenance temperature), the slurry cup is taken out after heat preservation and maintenance are carried out for 2 hours, a valve rod at the lower end of the slurry cup is removed, the lower end of the slurry cup is immersed into a water barrel, the valve rod at the upper end of the slurry cup is connected with a nitrogen cylinder pressure reducing valve, an upper pressure reducing valve switch is opened, pressure test is started from 0.1MPa, the condition of bubble protrusion in the water barrel is observed, each time of pressure increase is carried out for 0.1MPa, pressure stabilization is carried out for 10 seconds, pressure increase observation is continued until gas breakthrough is carried out in the water barrel, and breakthrough pressure is recorded, and the breakthrough pressure is the tested breakthrough pressure is the pressure-bearing strength of the well wall reinforcing agent. The pressure-bearing strength obtained by testing the borehole wall strengthening agents of example 1, example 5, example 8 and example 28 at different curing temperatures is shown in table 2;
table 2 bearing strength of the borehole wall enhancers of examples 1, 5, 8 and 28
As is clear from table 2, the borehole wall enhancers of examples 1, 5, 8 and 28 had good stable gel state at 65 to 130 ℃ and breakthrough pressure range of 1.0 to 1.7MPa, indicating that the borehole wall enhancers of examples 1, 5, 8 and 28 had good pressure-bearing and high temperature resistance.
Experimental example 3
To test compatibility of the borehole wall enhancers of examples 1 to 28, borehole wall enhancers were added to the base slurry (the mass of the borehole wall enhancers was 5% of the mass of the base slurry) to prepare drilling fluids; the base slurry consists of the following components in percentage by mass: 2% of main emulsifier, 2.4% of auxiliary emulsifier, 2.5% of organic soil, 3% of alkaline regulator, 2% of wetting agent, 4% of fluid loss agent (oxidized asphalt), 20% of calcium chloride aqueous solution with the mass fraction of 25%, and the balance of mixed solvent consisting of diesel oil and water with the volume ratio of 4:1; the main emulsifier is sodium hydroxypropyl methacrylate, the auxiliary emulsifier is allyloxy nonylphenol polyoxyethylene ether, the alkaline regulator is calcium oxide, and the wetting agent is sodium allyloxy hydroxypropyl sulfonate. Then, a digital display rotary viscometer (six-speed rotary viscometer) is adopted to measure the viscosity of the drilling fluid, and the testing method refers to the standard GB/T16783.1-2006, part 1 of field test of drilling fluid in petroleum and natural gas industry: the rheological property is measured by the method in oil-based drilling fluid, and readings of 600r/min, 300r/min and 100r/min when the dial is stable are recorded respectively, and meanwhile, the method is used for testing part 1 of the petroleum and natural gas industrial drilling fluid on site according to the standard GB/T16783.1-2006: the method in oil-based drilling fluid was used to test the breaking voltage of drilling fluid and the results are shown in table 3.
TABLE 3 compatibility of borehole wall enhancers of examples 1-28
/>
As can be seen from Table 3, the borehole wall enhancers of examples 1-28 had less effect on the viscosity of the base slurry, and the rheological property variation range substantially satisfied the field construction requirements. The increased emulsion breaking voltage indicates that the borehole wall enhancers of examples 1-28 can enhance the stability of the system.
Experimental example 4
To evaluate the plugging properties of the drilling fluids prepared with the wellbore wall enhancers of examples 1 to 35 and comparative examples 1 to 6, the wellbore wall enhancers of examples 1 to 35 and comparative examples 1 to 6 were prepared into drilling fluids according to the method in experimental example 3, and then the plugging properties of the base slurry and each drilling fluid were measured according to API specifications using a non-permeability tester (visual sand bed filtrate reducer). The test method is as follows: adding sand with granularity of 10-50 meshes into a cylinder of a visual sand bed filtration instrument, compacting and paving to form a sand bed, slowly adding 500mL of base slurry or drilling fluid into the cylinder, standing for 10min, and measuring the immersion depth (L) 1 ) Then gradually pressurizing to 0.69MPa, and measuring the depth (L) of the base slurry or drilling fluid immersed in the sand bed after 10min 2 ) The method comprises the steps of carrying out a first treatment on the surface of the The test results are shown in Table 4.
TABLE 4 base stock and examples 1-35 and comparative examples
Plugging property of drilling fluid prepared from 1-6 well wall reinforcing agent
/>
As is clear from Table 4, the well drilling fluids prepared with the well wall strengthening agents of examples 1 to 28 have good leakage preventing effect and good plugging performance. In addition, the preparation process of the well wall reinforcing agent in the embodiment 1-28 is simple, has no pollution to the environment and low cost, can be uniformly dispersed in drilling fluid, can improve rheological property, pressure resistance and the like of the drilling fluid, can effectively block micro-nano cracks of the well wall through adsorption and deformation filling effects, keeps the well wall stable, can effectively solve the problem of drilling fluid leakage of hard brittle shale and shale oil-gas stratum, and has wide application prospect.
When the amino modified silicon dioxide is prepared by adopting polyether solution with mass fraction of 5% and 40% and polyvinyl alcohol solution with mass fraction of 5% and 10% and adopting polyvinyl alcohol solution with mass fraction of 50g and 70g, hydrochloric acid with mass fraction of 10% and 37% and ammonia water with concentration of 5mol/L and 8mol/L, and drying temperature of 25 ℃ and 60 ℃ and drying time of 6h and 12h, the prepared amino modified silicon dioxide is used for preparing the well wall reinforcing agent of the example 1, and the sealing performance of the prepared well wall reinforcing agent is similar to that of the well wall reinforcing agent of the example 1.
Claims (10)
1. A well wall strengthening agent is characterized by being mainly prepared from amino modified silicon dioxide and a eutectic solvent, wherein the eutectic solvent comprises a hydrogen bond donor and a hydrogen bond acceptor, and the hydrogen bond donor is selected from C 1 ～C 5 One or any combination of carboxylic acid, phenylacetic acid, amino acid, glycerol, polyethylene glycol, glucose and butanediol, wherein the hydrogen bond acceptor comprises choline chloride, and the mass ratio of the hydrogen bond donor to the hydrogen bond acceptor is (1-16): 1; the ratio of the mass of the amino-modified silicon dioxide to the mass of the choline chloride in the eutectic solvent is (0.01-0.1): 1.
2. The wellbore wall strengthening agent of claim 1, wherein C 1 ～C 5 The carboxylic acid is selected from one or any combination of formic acid, acetic acid and propionic acid.
3. The borehole wall enhancer of claim 1 wherein the amino modified silica is prepared from silica modified with amino groups; the amino modification method comprises the following steps: soaking the silicon dioxide with the average particle size of 20-500 nm in ammonia water, washing and drying to obtain the amino modified silicon dioxide.
4. A borehole wall enhancer as set forth in claim 3 wherein the volume of ammonia water corresponding to each 5g of silica having an average particle diameter of 20 to 500nm is 20 to 60mL; the concentration of the ammonia water is 5-10 mol/L.
5. The borehole wall enhancer of claim 3, wherein the soaking time is not less than 3 hours; the washing is to wash the soaked system to neutrality.
6. The borehole wall enhancer of claim 3, wherein the drying temperature is 25-60 ℃ for 6-12 hours.
7. The borehole wall enhancer of any one of claims 3-6, wherein the silica having an average particle size of 20-500 nm is prepared by a process comprising the steps of: uniformly mixing a polyether solution, water, hydrochloric acid and a polyvinyl alcohol solution, adding tetraalkyl orthosilicate, mixing and reacting for at least 10min, standing the mixed and reacted system for at least 12h, mixing the standing system for at least 12h, carrying out hydrothermal treatment on the mixed system, carrying out solid-liquid separation, washing, drying, and calcining the dried solid to obtain the silicon dioxide with the average particle size of 20-500 nm.
8. The borehole wall enhancer of claim 7, wherein the polyether solution has a mass fraction of 5-40%; the mass of the polyether solution adopted for every 40mL of water is 10-50 g; the mass fraction of the hydrochloric acid is 10-37%; the volume of hydrochloric acid adopted for each 40mL of water is 5-15 mL; every 40mL of water corresponds to 3 to 6g of the mass of the adopted tetra-alkyl orthosilicate; the temperature of the hydrothermal treatment is 80-120 ℃ and the time is 12-36 h; the calcining temperature is 500-600 ℃ and the calcining time is 3-6 h.
9. A method of preparing a borehole wall enhancer as claimed in any one of claims 1 to 8, comprising the steps of: and uniformly mixing the amino modified silicon dioxide with the formula amount and the eutectic solvent to obtain the well wall strengthening agent.
10. Use of a borehole wall enhancer as claimed in any one of claims 1 to 8 in a drilling fluid.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202310428180.2A CN116496765A (en) | 2023-04-20 | 2023-04-20 | Borehole wall reinforcing agent, and preparation method and application thereof |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202310428180.2A CN116496765A (en) | 2023-04-20 | 2023-04-20 | Borehole wall reinforcing agent, and preparation method and application thereof |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN116496765A true CN116496765A (en) | 2023-07-28 |
Family
ID=87327869
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202310428180.2A Pending CN116496765A (en) | 2023-04-20 | 2023-04-20 | Borehole wall reinforcing agent, and preparation method and application thereof |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN116496765A (en) |
Citations (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US20120028855A1 (en) * | 2008-03-26 | 2012-02-02 | Shrieve Chemical Products | Shale hydration inhibition agent(s) and method of use |
| US20130043028A1 (en) * | 2011-08-19 | 2013-02-21 | Baker Hughes Incorporated | Method of cooling downhole element using nanoenhanced downhole fluid |
| CN109180503A (en) * | 2018-09-11 | 2019-01-11 | 中国石油大学(华东) | A kind of eutectic species shale control agent and its preparation method and application |
| CN111194344A (en) * | 2017-05-15 | 2020-05-22 | 沙特阿拉伯石油公司 | Compositions and methods for water and gas plugging in subterranean formations |
| US20210230470A1 (en) * | 2020-01-28 | 2021-07-29 | Uti Limited Partnership | Reservoir Emplacement Of Rheologically Tuned And Timed Nanoparticle Emulsions |
| CN113278118A (en) * | 2021-07-22 | 2021-08-20 | 山东聚星石油科技有限公司 | Temperature-resistant and salt-resistant nano polymer emulsion and synthesis method and application thereof |
| CN114425181A (en) * | 2020-10-10 | 2022-05-03 | 中国石油化工股份有限公司 | Porous liquid material and preparation method and application thereof |
| CN115895765A (en) * | 2022-11-25 | 2023-04-04 | 江苏大学 | Additive for lubricating liquid and ionic liquid-like lubricating liquid |
| US20240010903A1 (en) * | 2020-11-12 | 2024-01-11 | Uniquem Inc. | Deep eutectic solvents |
-
2023
- 2023-04-20 CN CN202310428180.2A patent/CN116496765A/en active Pending
Patent Citations (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US20120028855A1 (en) * | 2008-03-26 | 2012-02-02 | Shrieve Chemical Products | Shale hydration inhibition agent(s) and method of use |
| US20130043028A1 (en) * | 2011-08-19 | 2013-02-21 | Baker Hughes Incorporated | Method of cooling downhole element using nanoenhanced downhole fluid |
| CN111194344A (en) * | 2017-05-15 | 2020-05-22 | 沙特阿拉伯石油公司 | Compositions and methods for water and gas plugging in subterranean formations |
| CN109180503A (en) * | 2018-09-11 | 2019-01-11 | 中国石油大学(华东) | A kind of eutectic species shale control agent and its preparation method and application |
| US20210230470A1 (en) * | 2020-01-28 | 2021-07-29 | Uti Limited Partnership | Reservoir Emplacement Of Rheologically Tuned And Timed Nanoparticle Emulsions |
| CN114425181A (en) * | 2020-10-10 | 2022-05-03 | 中国石油化工股份有限公司 | Porous liquid material and preparation method and application thereof |
| US20240010903A1 (en) * | 2020-11-12 | 2024-01-11 | Uniquem Inc. | Deep eutectic solvents |
| CN113278118A (en) * | 2021-07-22 | 2021-08-20 | 山东聚星石油科技有限公司 | Temperature-resistant and salt-resistant nano polymer emulsion and synthesis method and application thereof |
| CN115895765A (en) * | 2022-11-25 | 2023-04-04 | 江苏大学 | Additive for lubricating liquid and ionic liquid-like lubricating liquid |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| US10011755B2 (en) | Viscous settable fluid for lost circulation in subterranean formations | |
| WO2015109917A1 (en) | Thickener for shale gas fracturing fluid, fracturing fluid and preparation method and use thereof | |
| CN112342001B (en) | Plugging agent and plugging slurry for oil-based drilling fluid and preparation method of plugging agent and plugging slurry | |
| CN103013470B (en) | A kind of high inhibition drilling fluid system | |
| WO2013169533A1 (en) | A calcium aluminate cement composition containing a set retarder of an organic acid and a polymeric mixture | |
| CN107572975B (en) | Plugging agent, preparation method and application thereof | |
| WO2022267968A1 (en) | Synthesis of organic-inorganic nano-composite gel plugging agent, and oil-based drilling fluid | |
| CN105295872A (en) | Drilling fluid suitable for compact sandstone reservoir | |
| US9738821B2 (en) | Amphoteric polymer suspending agent for use in calcium aluminate cement compositions | |
| Ay et al. | An experimental study of silicate–polymer gel systems to seal shallow water flow and lost circulation zones in top hole drilling | |
| CN109135696B (en) | High-temperature high-density drilling fluid with strong suspension stability and preparation method thereof | |
| CN113122197A (en) | Shale oil horizontal well drilling fluid and preparation method thereof | |
| CN105969326B (en) | Sodium metasilicate Cementing | |
| CN113004879A (en) | Well wall pressure-bearing plugging agent and preparation method thereof | |
| CN113185955A (en) | Oil-based drilling fluid and preparation method and application thereof | |
| CN105715229B (en) | One kind being suitable for continuous oil pipe operation note cement cap and its application process | |
| CN116496765A (en) | Borehole wall reinforcing agent, and preparation method and application thereof | |
| RU2340761C1 (en) | Method of elimination of leakage of producing well column | |
| CN111748328A (en) | Ultrahigh-temperature long-acting stable oil-based well completion fluid and preparation method thereof | |
| CN113773820B (en) | Pressure-bearing leakage-blocking slurry and preparation method and application thereof | |
| CN109021944B (en) | Oil layer protective agent | |
| CN110760295B (en) | High-temperature tackifier for oil well cement slurry and preparation method thereof | |
| CN105238371A (en) | Polyethylene wax type drilling fluid and preparation method thereof | |
| CA2918017C (en) | Liquid additive for cement resiliency | |
| CN110713822A (en) | High-temperature high-density oil-based drilling fluid |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination |