CN109837072B - Water-based drilling fluid with strong inhibition and strong plugging property and suitable for shale formation and preparation method thereof - Google Patents
Water-based drilling fluid with strong inhibition and strong plugging property and suitable for shale formation and preparation method thereof Download PDFInfo
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- 238000005553 drilling Methods 0.000 title claims abstract description 96
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 79
- 239000012530 fluid Substances 0.000 title claims abstract description 78
- 230000015572 biosynthetic process Effects 0.000 title claims abstract description 34
- 230000005764 inhibitory process Effects 0.000 title claims abstract description 33
- 238000002360 preparation method Methods 0.000 title claims abstract description 9
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 48
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical compound [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 claims abstract description 24
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical compound [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 claims abstract description 22
- 239000000314 lubricant Substances 0.000 claims abstract description 22
- 239000000440 bentonite Substances 0.000 claims abstract description 19
- 229910000278 bentonite Inorganic materials 0.000 claims abstract description 19
- SVPXDRXYRYOSEX-UHFFFAOYSA-N bentoquatam Chemical compound O.O=[Si]=O.O=[Al]O[Al]=O SVPXDRXYRYOSEX-UHFFFAOYSA-N 0.000 claims abstract description 19
- 239000000706 filtrate Substances 0.000 claims abstract description 13
- 239000001103 potassium chloride Substances 0.000 claims abstract description 11
- 235000011164 potassium chloride Nutrition 0.000 claims abstract description 11
- 239000003638 chemical reducing agent Substances 0.000 claims abstract description 10
- 229920000768 polyamine Polymers 0.000 claims abstract description 10
- 229910000029 sodium carbonate Inorganic materials 0.000 claims abstract description 10
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical class [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 claims description 63
- 238000003756 stirring Methods 0.000 claims description 56
- VTYYLEPIZMXCLO-UHFFFAOYSA-L Calcium carbonate Chemical compound [Ca+2].[O-]C([O-])=O VTYYLEPIZMXCLO-UHFFFAOYSA-L 0.000 claims description 32
- KWYUFKZDYYNOTN-UHFFFAOYSA-M Potassium hydroxide Chemical compound [OH-].[K+] KWYUFKZDYYNOTN-UHFFFAOYSA-M 0.000 claims description 30
- 229910021389 graphene Inorganic materials 0.000 claims description 22
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims description 21
- NBIIXXVUZAFLBC-UHFFFAOYSA-N Phosphoric acid Chemical compound OP(O)(O)=O NBIIXXVUZAFLBC-UHFFFAOYSA-N 0.000 claims description 20
- 239000000243 solution Substances 0.000 claims description 19
- 239000000178 monomer Substances 0.000 claims description 18
- 239000000203 mixture Substances 0.000 claims description 17
- 229910000019 calcium carbonate Inorganic materials 0.000 claims description 15
- 239000003054 catalyst Substances 0.000 claims description 14
- 229910002804 graphite Inorganic materials 0.000 claims description 14
- 239000010439 graphite Substances 0.000 claims description 14
- 239000003112 inhibitor Substances 0.000 claims description 14
- QAOWNCQODCNURD-UHFFFAOYSA-N Sulfuric acid Chemical compound OS(O)(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-N 0.000 claims description 13
- 238000006243 chemical reaction Methods 0.000 claims description 13
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 12
- 239000002253 acid Substances 0.000 claims description 11
- 150000001412 amines Chemical class 0.000 claims description 11
- 230000001590 oxidative effect Effects 0.000 claims description 11
- MHAJPDPJQMAIIY-UHFFFAOYSA-N Hydrogen peroxide Chemical compound OO MHAJPDPJQMAIIY-UHFFFAOYSA-N 0.000 claims description 10
- 229910000147 aluminium phosphate Inorganic materials 0.000 claims description 10
- 238000000034 method Methods 0.000 claims description 10
- 239000004113 Sepiolite Substances 0.000 claims description 9
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical group [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 claims description 9
- 239000010426 asphalt Substances 0.000 claims description 9
- 239000000839 emulsion Substances 0.000 claims description 9
- 239000005543 nano-size silicon particle Substances 0.000 claims description 9
- 239000012188 paraffin wax Substances 0.000 claims description 9
- 239000012286 potassium permanganate Substances 0.000 claims description 9
- 229910052624 sepiolite Inorganic materials 0.000 claims description 9
- 235000019355 sepiolite Nutrition 0.000 claims description 9
- 235000012239 silicon dioxide Nutrition 0.000 claims description 9
- 235000017550 sodium carbonate Nutrition 0.000 claims description 9
- 239000007795 chemical reaction product Substances 0.000 claims description 7
- 239000012065 filter cake Substances 0.000 claims description 7
- 238000001914 filtration Methods 0.000 claims description 7
- 238000009775 high-speed stirring Methods 0.000 claims description 7
- 239000002245 particle Substances 0.000 claims description 7
- 238000007789 sealing Methods 0.000 claims description 7
- 229920000881 Modified starch Polymers 0.000 claims description 6
- 239000004368 Modified starch Substances 0.000 claims description 6
- DPXJVFZANSGRMM-UHFFFAOYSA-N acetic acid;2,3,4,5,6-pentahydroxyhexanal;sodium Chemical compound [Na].CC(O)=O.OCC(O)C(O)C(O)C(O)C=O DPXJVFZANSGRMM-UHFFFAOYSA-N 0.000 claims description 6
- 239000001768 carboxy methyl cellulose Substances 0.000 claims description 6
- 239000012153 distilled water Substances 0.000 claims description 6
- 235000019426 modified starch Nutrition 0.000 claims description 6
- 229910052757 nitrogen Inorganic materials 0.000 claims description 6
- 230000001105 regulatory effect Effects 0.000 claims description 6
- 235000019812 sodium carboxymethyl cellulose Nutrition 0.000 claims description 6
- 229920001027 sodium carboxymethylcellulose Polymers 0.000 claims description 6
- 235000015112 vegetable and seed oil Nutrition 0.000 claims description 6
- 239000008158 vegetable oil Substances 0.000 claims description 6
- 238000005406 washing Methods 0.000 claims description 6
- 239000008367 deionised water Substances 0.000 claims description 5
- 229910021641 deionized water Inorganic materials 0.000 claims description 5
- 239000011259 mixed solution Substances 0.000 claims description 5
- 239000000126 substance Substances 0.000 claims description 5
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 claims description 4
- 239000000654 additive Substances 0.000 claims description 4
- 230000000996 additive effect Effects 0.000 claims description 4
- ROOXNKNUYICQNP-UHFFFAOYSA-N ammonium persulfate Chemical compound [NH4+].[NH4+].[O-]S(=O)(=O)OOS([O-])(=O)=O ROOXNKNUYICQNP-UHFFFAOYSA-N 0.000 claims description 4
- 239000006185 dispersion Substances 0.000 claims description 4
- 239000000835 fiber Substances 0.000 claims description 4
- 239000001257 hydrogen Substances 0.000 claims description 4
- 229910052739 hydrogen Inorganic materials 0.000 claims description 4
- VLTRZXGMWDSKGL-UHFFFAOYSA-N perchloric acid Chemical compound OCl(=O)(=O)=O VLTRZXGMWDSKGL-UHFFFAOYSA-N 0.000 claims description 4
- FFRBMBIXVSCUFS-UHFFFAOYSA-N 2,4-dinitro-1-naphthol Chemical group C1=CC=C2C(O)=C([N+]([O-])=O)C=C([N+]([O-])=O)C2=C1 FFRBMBIXVSCUFS-UHFFFAOYSA-N 0.000 claims description 3
- 239000004721 Polyphenylene oxide Substances 0.000 claims description 3
- HKVFISRIUUGTIB-UHFFFAOYSA-O azanium;cerium;nitrate Chemical compound [NH4+].[Ce].[O-][N+]([O-])=O HKVFISRIUUGTIB-UHFFFAOYSA-O 0.000 claims description 3
- 238000001035 drying Methods 0.000 claims description 3
- 238000004108 freeze drying Methods 0.000 claims description 3
- 229920000578 graft copolymer Polymers 0.000 claims description 3
- 238000000227 grinding Methods 0.000 claims description 3
- 238000010438 heat treatment Methods 0.000 claims description 3
- 125000004029 hydroxymethyl group Chemical group [H]OC([H])([H])* 0.000 claims description 3
- 239000005457 ice water Substances 0.000 claims description 3
- 238000002156 mixing Methods 0.000 claims description 3
- 230000007935 neutral effect Effects 0.000 claims description 3
- 229920000570 polyether Polymers 0.000 claims description 3
- 238000001556 precipitation Methods 0.000 claims description 3
- 238000000967 suction filtration Methods 0.000 claims description 3
- LCPVQAHEFVXVKT-UHFFFAOYSA-N 2-(2,4-difluorophenoxy)pyridin-3-amine Chemical compound NC1=CC=CN=C1OC1=CC=C(F)C=C1F LCPVQAHEFVXVKT-UHFFFAOYSA-N 0.000 claims description 2
- GRYLNZFGIOXLOG-UHFFFAOYSA-N Nitric acid Chemical compound O[N+]([O-])=O GRYLNZFGIOXLOG-UHFFFAOYSA-N 0.000 claims description 2
- IOVCWXUNBOPUCH-UHFFFAOYSA-N Nitrous acid Chemical compound ON=O IOVCWXUNBOPUCH-UHFFFAOYSA-N 0.000 claims description 2
- 125000003368 amide group Chemical group 0.000 claims description 2
- 229910001870 ammonium persulfate Inorganic materials 0.000 claims description 2
- 229920002678 cellulose Polymers 0.000 claims description 2
- 239000001913 cellulose Substances 0.000 claims description 2
- QCCDYNYSHILRDG-UHFFFAOYSA-K cerium(3+);trifluoride Chemical compound [F-].[F-].[F-].[Ce+3] QCCDYNYSHILRDG-UHFFFAOYSA-K 0.000 claims description 2
- OZECDDHOAMNMQI-UHFFFAOYSA-H cerium(3+);trisulfate Chemical compound [Ce+3].[Ce+3].[O-]S([O-])(=O)=O.[O-]S([O-])(=O)=O.[O-]S([O-])(=O)=O OZECDDHOAMNMQI-UHFFFAOYSA-H 0.000 claims description 2
- 239000012295 chemical reaction liquid Substances 0.000 claims description 2
- 239000002131 composite material Substances 0.000 claims description 2
- QWPPOHNGKGFGJK-UHFFFAOYSA-N hypochlorous acid Chemical compound ClO QWPPOHNGKGFGJK-UHFFFAOYSA-N 0.000 claims description 2
- 239000002480 mineral oil Substances 0.000 claims description 2
- 235000010446 mineral oil Nutrition 0.000 claims description 2
- 229910017604 nitric acid Inorganic materials 0.000 claims description 2
- USHAGKDGDHPEEY-UHFFFAOYSA-L potassium persulfate Chemical compound [K+].[K+].[O-]S(=O)(=O)OOS([O-])(=O)=O USHAGKDGDHPEEY-UHFFFAOYSA-L 0.000 claims description 2
- CHQMHPLRPQMAMX-UHFFFAOYSA-L sodium persulfate Substances [Na+].[Na+].[O-]S(=O)(=O)OOS([O-])(=O)=O CHQMHPLRPQMAMX-UHFFFAOYSA-L 0.000 claims description 2
- 150000005846 sugar alcohols Polymers 0.000 claims description 2
- 229920001059 synthetic polymer Polymers 0.000 claims description 2
- 239000000463 material Substances 0.000 abstract description 18
- 239000004927 clay Substances 0.000 abstract description 11
- 230000036571 hydration Effects 0.000 abstract description 9
- 238000006703 hydration reaction Methods 0.000 abstract description 9
- 238000005755 formation reaction Methods 0.000 description 17
- 235000010216 calcium carbonate Nutrition 0.000 description 12
- 239000007789 gas Substances 0.000 description 11
- 238000011161 development Methods 0.000 description 10
- 230000000694 effects Effects 0.000 description 9
- 239000011148 porous material Substances 0.000 description 8
- 238000012360 testing method Methods 0.000 description 8
- 230000000052 comparative effect Effects 0.000 description 7
- TZCXTZWJZNENPQ-UHFFFAOYSA-L barium sulfate Chemical compound [Ba+2].[O-]S([O-])(=O)=O TZCXTZWJZNENPQ-UHFFFAOYSA-L 0.000 description 6
- 230000002401 inhibitory effect Effects 0.000 description 5
- 239000003208 petroleum Substances 0.000 description 5
- 239000008399 tap water Substances 0.000 description 5
- 235000020679 tap water Nutrition 0.000 description 5
- 239000000230 xanthan gum Substances 0.000 description 4
- 229920001285 xanthan gum Polymers 0.000 description 4
- 235000010493 xanthan gum Nutrition 0.000 description 4
- 229940082509 xanthan gum Drugs 0.000 description 4
- 229920000642 polymer Polymers 0.000 description 3
- XAEFZNCEHLXOMS-UHFFFAOYSA-M potassium benzoate Chemical compound [K+].[O-]C(=O)C1=CC=CC=C1 XAEFZNCEHLXOMS-UHFFFAOYSA-M 0.000 description 3
- 239000000843 powder Substances 0.000 description 3
- 229910001415 sodium ion Inorganic materials 0.000 description 3
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 2
- CNCOEDDPFOAUMB-UHFFFAOYSA-N N-Methylolacrylamide Chemical compound OCNC(=O)C=C CNCOEDDPFOAUMB-UHFFFAOYSA-N 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 2
- 239000013043 chemical agent Substances 0.000 description 2
- 239000002734 clay mineral Substances 0.000 description 2
- 239000013078 crystal Substances 0.000 description 2
- GQOKIYDTHHZSCJ-UHFFFAOYSA-M dimethyl-bis(prop-2-enyl)azanium;chloride Chemical group [Cl-].C=CC[N+](C)(C)CC=C GQOKIYDTHHZSCJ-UHFFFAOYSA-M 0.000 description 2
- 230000005611 electricity Effects 0.000 description 2
- 239000013067 intermediate product Substances 0.000 description 2
- 238000005461 lubrication Methods 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 229910001414 potassium ion Inorganic materials 0.000 description 2
- 125000002924 primary amino group Chemical group [H]N([H])* 0.000 description 2
- 230000001737 promoting effect Effects 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- 238000000518 rheometry Methods 0.000 description 2
- 239000004576 sand Substances 0.000 description 2
- 201000005488 Capillary Leak Syndrome Diseases 0.000 description 1
- 229920002134 Carboxymethyl cellulose Polymers 0.000 description 1
- 150000000703 Cerium Chemical class 0.000 description 1
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 description 1
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 description 1
- -1 SMSL Substances 0.000 description 1
- 208000031932 Systemic capillary leak syndrome Diseases 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 238000005054 agglomeration Methods 0.000 description 1
- 230000002776 aggregation Effects 0.000 description 1
- 150000003863 ammonium salts Chemical class 0.000 description 1
- 230000033228 biological regulation Effects 0.000 description 1
- 229920001222 biopolymer Polymers 0.000 description 1
- 239000004566 building material Substances 0.000 description 1
- 159000000007 calcium salts Chemical class 0.000 description 1
- XMPZTFVPEKAKFH-UHFFFAOYSA-P ceric ammonium nitrate Chemical compound [NH4+].[NH4+].[Ce+4].[O-][N+]([O-])=O.[O-][N+]([O-])=O.[O-][N+]([O-])=O.[O-][N+]([O-])=O.[O-][N+]([O-])=O.[O-][N+]([O-])=O XMPZTFVPEKAKFH-UHFFFAOYSA-P 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
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- 238000009826 distribution Methods 0.000 description 1
- 230000001804 emulsifying effect Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
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- 235000013312 flour Nutrition 0.000 description 1
- 229910052949 galena Inorganic materials 0.000 description 1
- 229920001477 hydrophilic polymer Polymers 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 150000002500 ions Chemical class 0.000 description 1
- 229910052742 iron Inorganic materials 0.000 description 1
- XCAUINMIESBTBL-UHFFFAOYSA-N lead(ii) sulfide Chemical compound [Pb]=S XCAUINMIESBTBL-UHFFFAOYSA-N 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 230000001050 lubricating effect Effects 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 239000012528 membrane Substances 0.000 description 1
- 125000002496 methyl group Chemical group [H]C([H])([H])* 0.000 description 1
- 238000001471 micro-filtration Methods 0.000 description 1
- 239000002086 nanomaterial Substances 0.000 description 1
- 239000002135 nanosheet Substances 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 239000003921 oil Substances 0.000 description 1
- 239000005416 organic matter Substances 0.000 description 1
- 238000011056 performance test Methods 0.000 description 1
- JRKICGRDRMAZLK-UHFFFAOYSA-L persulfate group Chemical group S(=O)(=O)([O-])OOS(=O)(=O)[O-] JRKICGRDRMAZLK-UHFFFAOYSA-L 0.000 description 1
- 239000003209 petroleum derivative Substances 0.000 description 1
- 229910052698 phosphorus Inorganic materials 0.000 description 1
- 229920002401 polyacrylamide Polymers 0.000 description 1
- 229920005862 polyol Polymers 0.000 description 1
- 150000003077 polyols Chemical class 0.000 description 1
- 230000002265 prevention Effects 0.000 description 1
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- 239000002994 raw material Substances 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 230000035945 sensitivity Effects 0.000 description 1
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Landscapes
- Curing Cements, Concrete, And Artificial Stone (AREA)
- Sealing Material Composition (AREA)
Abstract
The invention relates to a water-based drilling fluid with strong inhibition and strong plugging property suitable for a shale stratum and a preparation method thereof, belonging to the field of drilling. The water-based drilling fluid with strong inhibition and strong plugging property suitable for the shale formation comprises the following components in parts by weight: 100 parts of water; 1-3 parts of bentonite; 0.5-4 parts of a filtrate reducer; 0-0.7 part of flow pattern regulator; 2.5-5.5 parts of a plugging anti-collapse agent; 0.5-4.5 parts of a nano plugging anti-collapse agent; 4-9 parts of an anti-collapse agent; 1-5 parts of a lubricant; 0-170 parts of density regulator; the amount of the sodium carbonate is 4-6% of the weight of the bentonite. The invention adopts potassium chloride and polyamine to inhibit the clay hydration capacity of the shale formation, and a plurality of nano plugging materials and micro plugging materials can form a compact plugging layer, thereby realizing the effective plugging of shale formation micropore seams, having better rheological property and lubricity and better overall performance, and being capable of meeting the requirements of shale gas long horizontal section drilling.
Description
Technical Field
The invention relates to a water-based drilling fluid in the field of drilling, in particular to a water-based drilling fluid with strong inhibition and strong plugging property suitable for a shale stratum and a preparation method thereof.
Background
Shale gas development is an important direction for changing the oil and gas resource exploration and development pattern in China and cultivating new industries of strategies. The development of shale gas in China starts late, and the knowledge of shale gas strata and the drilling development technical level are relatively low. In the actual drilling process, the condition of borehole wall instability of the mud shale with strong water sensitivity is often generated when the well is drilled, great difficulty is brought to safe well drilling and completion construction, well collapse, drill sticking and other underground complex conditions are often caused, the non-production time is increased, a production layer is polluted, even a borehole is scrapped, and great economic loss is caused.
The technical problem that the borehole wall instability of the shale stratum is always puzzled on the drilling engineering is solved. During drilling, over 90% of borehole wall instability is caused by shale formation instability. The main reasons of the method are that water-sensitive clay minerals in the shale stratum are hydrated when meeting the water phase of the drilling fluid, so that clay particles are expanded and dispersed, hydration stress is generated, and the cementing strength of the shale is reduced; secondly, shale stratum cracks and bedding development exist, a large number of cracks exist, drilling fluid enters the cracks rapidly under the action of pressure and invades into the deep part of the stratum along the cracks, the stratum pressure is caused to rise rapidly, the stress distribution of the well wall is changed in a short time, and the weak zone of the well wall is unstable. Therefore, the inhibition and plugging capability of the drilling fluid are improved, and the drilling fluid is an important means for keeping the stability of the well wall of the shale formation.
In recent years, with the demand of shale gas exploration and development, a series of water-based drilling fluid systems for inhibiting and plugging are developed in China. In the aspect of inhibition, water-soluble chemical agents such as sodium salt, potassium salt, calcium salt, ammonium salt, organic amine (such as polyamine, polyether amine and the like), polyhydroxy organic matter (such as polyol, polymeric alcohol and the like) and the like are mostly adopted, and one or more chemical agents synergistically play a strong inhibition role in clay hydration. In the aspect of plugging property, a conventional plugging material and/or a nano plugging material is mostly adopted to plug a shale formation, but how to effectively plug micro cracks and micro pores existing in the shale formation, so that drilling fluid and filtrate are reduced or prevented from invading the shale formation as much as possible, the stable state of the shale formation is maintained to the maximum extent, and the technical problem to be solved still needs to be solved urgently.
Chinese patent with publication number 106634900A (application number CN201610882474.2) proposes a strong-inhibition nano plugging water-based drilling fluid for shale, potassium chloride and polyacrylamide potassium salt are used as inhibitors in the aspect of inhibition, potassium ions are embedded into clay crystal layers to have certain inhibition effect, but the effect of tensioning the space between the clay crystal layers by multi-point adsorption is not achieved; the plugging material adopts calcium carbonate and nano-silica, has certain plugging capability, but is lack of deformable and fibrous plugging material, is not beneficial to forming a compact plugging layer, and has poor plugging effect on cracks of micron or more; the pH value regulator adopts sodium hydroxide, but sodium ions have the function of promoting clay hydration and are not beneficial to fully exerting inhibition of the drilling fluid.
Therefore, the research on the effective plugging of the microcracks and the micropores of the shale stratum by the water-based drilling fluid and the improvement of the shale stratum stability of the drilling fluid have important practical significance.
Disclosure of Invention
In order to solve the problems in the prior art, the invention provides a water-based drilling fluid with strong inhibition and strong plugging property, which is suitable for shale formations. In particular to a water-based drilling fluid with strong inhibition and strong plugging property suitable for a shale stratum and a preparation method thereof. The shale gas horizontal well plugging agent has strong inhibition and plugging properties, and is suitable for the requirements of drilling exploration and development of shale gas horizontal wells.
One purpose of the invention is to provide a strong-inhibition strong-plugging water-based drilling fluid suitable for shale formation, which comprises the following components in parts by weight:
100 parts of water;
1-3 parts of bentonite, preferably 1.0-2.5 parts; materials for making slurry by the drilling fluid;
0.5-4 parts of a filtrate reducer, preferably 1.0-4.0 parts; drilling fluid loss wall building materials;
0-0.7 part of flow pattern regulator, preferably 0.1-0.5 part; materials for adjusting rheological properties of drilling fluid;
2.5-5.5 parts of plugging anti-collapse agent, preferably 3-5 parts; the drilling fluid is a material for plugging pores and cracks with the diameter of more than micron;
0.5-4.5 parts of nano plugging anti-collapse agent, preferably 1-4 parts; the drilling fluid is used for plugging pores and cracks below the micron level of the stratum;
4-9 parts of an anti-collapse agent, preferably 5-9 parts; materials for inhibiting hydration of stratum clay minerals by the drilling fluid;
1-5 parts of a lubricant, preferably 2-4 parts; materials that improve the lubricity of the drilling fluid;
0-170 parts of density regulator;
and the bentonite also comprises sodium carbonate, and the dosage of the sodium carbonate is 4-6% of the weight of the bentonite.
Most preferably:
100 parts of water;
1.0-2.5 parts of bentonite;
1.0-4.0 parts of a filtrate reducer;
0.1-0.5 part of flow pattern regulator;
3-5 parts of a plugging anti-collapse agent;
1-4 parts of a nano plugging anti-collapse agent;
5-9 parts of an anti-collapse agent;
2-4 parts of a lubricant;
0-170 parts of density regulator;
and the bentonite also comprises sodium carbonate, and the dosage of the sodium carbonate is 4-6% of the weight of the bentonite.
The pH value regulator can be further included, and the pH value is regulated to 8-10 by the pH value regulator; the pH value regulator can be selected from sodium hydroxide and/or potassium hydroxide, and is preferably potassium hydroxide; the pH value regulator is used for keeping the drilling fluid alkaline; in specific practice, the amount of the pH regulator is generally 0.1 to 0.7 part, preferably 0.1 to 0.5 part, based on 100 parts by weight of the application water.
The density regulator can be used according to actual needsThe density is adjusted to 1.2-2.0 g/cm3. The density regulator can be selected from barite powder, iron ore powder, Qing mountain flour and galena powder, and is preferably barite powder.
The fluid loss additive is at least one selected from sodium carboxymethyl cellulose, polyanionic cellulose and modified starch.
The flow pattern regulator is biogel and synthetic polymer, preferably is a biopolymer XC.
Considering that sodium ions can promote clay dispersion, potassium hydroxide is preferably adopted as the pH value regulator of the pH value regulator, so that the pH value regulation requirement is met, potassium ions can be provided, and the inhibition characteristic of the drilling fluid is facilitated.
The plugging anti-collapse agent is a mixture of sulfonated asphalt, superfine calcium carbonate and sepiolite fiber plugging agent, and the mass ratio of the plugging anti-collapse agent to the plugging agent is (1.5-2.5): 0.5-1.5), preferably 2:2: 1; wherein the sulfonated asphalt can be low softening point sulfonated asphalt FT-1; the superfine calcium carbonate is a mixture of superfine calcium carbonates with different particle sizes, and specifically, the dosage of the superfine calcium carbonate with 200 meshes, 400 meshes, 800 meshes and 1250 meshes is (0.5-1.5), (1.5-2.5), (0.5-1.5), and preferably 1:2:2: 1; the length of the sepiolite fiber plugging agent is 50-100 mu m.
The nano plugging anti-collapse agent is a mixture of nano paraffin emulsion, nano silicon dioxide and modified graphene oxide; wherein the mass ratio of the nano paraffin emulsion, the nano silicon dioxide and the modified graphene oxide is (2.5-3.5): 1.5-2.5).
The modified graphene oxide is prepared by taking concentrated sulfuric acid, phosphoric acid, potassium permanganate and graphite as raw materials, carrying out a series of reactions to obtain an intermediate product, grafting a polymer on the surface of the intermediate product to obtain the modified graphene oxide, and reacting the modified graphene oxide with Na+、Ca2+、K+The agglomeration tendency is small under the ion condition, and the drilling fluid has good dispersibility; the modified graphene oxide has good flexibility, can be tightly attached to the surface of a shale well wall, effectively blocks nano-micron pores and microcracks of the shale, and prevents well drillingThe hydraulic pressure is transmitted to the deep part of the stratum, and the instability of the well wall is prevented. Compared with the defect that the common graphene oxide drilling fluid is easy to agglomerate and even settle, the graphene oxide nanosheet layer is not easy to agglomerate in the drilling fluid due to the steric hindrance effect of the polymer molecular chain on the surface of the graphene oxide after the polymer is grafted and modified. In addition, after the hydrophilic polymer with positive electricity is grafted on the surface, the affinity of the graphene oxide and the well wall shale with negative electricity is obviously improved, the graphene oxide is easier to be firmly adsorbed on the inner surface and the outer surface of the well wall, a compact film is formed, and the plugging and anti-collapse effects are improved.
Specifically, the modified graphene oxide can be prepared by a method comprising the following steps:
(1) placing graphite and an oxidizing acid solution in a reaction container, and stirring to fully mix the graphite and the oxidizing acid solution; mixing KMnO4Slowly adding the mixture into a reaction container in batches, stirring, placing the reaction container into an ice water bath after full reaction, adding water (the water can be distilled water or deionized water) to dilute reaction liquid, wherein the weight ratio of the water to the oxidizing acid solution can be 1 (0.3-0.5), and then adding hydrogen peroxide in batches until the reaction product is golden yellow; wherein the hydrogen peroxide is used for removing redundant potassium permanganate;
(2) then centrifuging and washing the reaction product until the pH value is neutral; finally, after centrifugal precipitation, re-dispersing the graphene oxide in water, and stirring to obtain a graphene oxide aqueous dispersion; performing suction filtration, and freeze-drying and grinding a filter cake to obtain graphene oxide;
(3) dispersing graphene oxide in water (the water can be selected from distilled water or deionized water), wherein the weight ratio of the graphene oxide to the water can be 1 (50-150); and then adding a polymerized monomer A and a polymerized monomer B, introducing nitrogen, heating to 50-70 ℃, then adding a solution containing a catalyst, stirring for reaction under the condition of introducing nitrogen, and filtering, washing and drying to obtain the modified graphene oxide of the surface graft polymer. Wherein,
in the step (1), the step (c),
the weight usage amount of the graphite and the oxidizing acid solution is 1 (20-40); the oxidizing acid solution is at least one of sulfuric acid, phosphoric acid, nitric acid, nitrous acid, perchloric acid and hypochlorous acid, and is preferably a mixed solution of concentrated sulfuric acid and phosphoric acid; more preferably a mixed solution of concentrated sulfuric acid and phosphoric acid, wherein the concentration of the concentrated sulfuric acid is 98%; the weight ratio of the concentrated sulfuric acid to the phosphoric acid is (4-7): 1;
the graphite and KMnO4The weight of the (A) is 1 (6-12);
the hydrogen peroxide and KMnO4The weight of the (C) is 1 (14-18).
In the step (3), the step (c),
the weight ratio of the graphene oxide to the polymerized monomer A is 1 (0.5-3), preferably 1 (1-2); the weight ratio of the graphene oxide to the polymerized monomer B is 1 (0.5-3), preferably 1 (1-2); the weight ratio of the catalyst to the total weight of the polymerized monomer A, B is (0.3-0.6) to 1; the weight concentration of the catalyst in the catalyst solution is 5-12%, preferably 8-10%;
the catalyst can be selected from at least one of tetravalent cerium salts such as ammonium cerium nitrate, cerium sulfate, cerium fluoride and the like, or at least one of persulfates such as potassium persulfate, ammonium persulfate, sodium persulfate and the like, and is preferably ammonium cerium nitrate.
In the step (3), the step (c),
the chemical structure of the polymerized monomer A is as follows:
formula (1)
In the formula (1), R1Is hydrogen or C1～C3Hydroxyalkyl, preferably hydrogen or hydroxymethyl; more preferably hydroxymethyl, i.e. monomer a is N-methylolacrylamide;
the chemical structure of the polymerized monomer B is as follows:
formula (2)
In the formula (2), R3Is C1～C2Alkyl groups of (a); preference is given toIs methyl, i.e. the monomer B is dimethyldiallylammonium chloride.
The modified graphene oxide can remarkably enhance the micro-crack plugging capability of the drilling fluid, so that the drilling fluid forms a compact plugging layer on the surface of shale, and the pressure transfer effect is effectively reduced.
The anti-collapse agent is selected from at least one of amine inhibitors such as polyamine, polyether amine and amine polyalcohol for drilling fluid and potassium chloride; wherein, based on 100 parts by weight of water, the addition amount of the amido inhibitor is 0.3-2 parts, and the addition amount of potassium chloride is 5-7 parts;
the lubricant is at least one selected from mineral oil modified lubricant, vegetable oil modified lubricant (containing extreme pressure element S, P and the like in the molecule), graphite and water-based lubricant.
The invention adopts potassium chloride and polyamine to inhibit the clay hydration capacity of the shale formation, and a plurality of nano plugging materials and micro plugging materials can form a compact plugging layer, thereby realizing the effective plugging of shale formation micropore seams, having better rheological property and lubricity and better overall performance, and being capable of meeting the requirements of shale gas long horizontal section drilling.
The invention also aims to provide a preparation method of the water-based drilling fluid with strong inhibition and strong plugging property, which is suitable for shale formation, and comprises the following steps:
adding the bentonite and the soda ash into water according to the dosage, uniformly stirring, and sealing and maintaining; adding the components including the filtrate reducer, the flow pattern regulator, the plugging and anti-collapse agent, the nano plugging and anti-collapse agent, the anti-collapse inhibitor and the lubricant under high-speed stirring, uniformly stirring, regulating the pH value to 8-10, and adding the density regulator to the required density to obtain the high-density composite material.
In particular, the method may comprise the steps of:
firstly, measuring tap water, sequentially adding drilling bentonite and soda under stirring at 600r/min, stirring for 30-60 min, and then sealing and maintaining for 24 h; adding the filtrate reducer according to the using amount and stirring for 5-10 min under the high-speed stirring of 7000r/min, adding the flow type regulator and stirring for 5-10 min, adding the plugging anti-collapse agent and stirring for 5-10 min, adding the nano plugging anti-collapse agent and stirring for 5-10 min, adding the anti-collapse agent and stirring for 15-20 min, adding potassium hydroxide and regulating the pH value to 8-10, adding the lubricant and stirring for 20-30 min, adding the density regulator such as barite powder to the required density and stirring for 15-20 min to prepare the strong-inhibition strong-plugging water-based drilling fluid suitable for the shale formation.
The existing plugging-inhibiting water-based drilling fluid has certain advantages in the aspects of inhibiting clay hydration, plugging stratum and the like, but effective plugging cannot be realized aiming at microcracks and microporosities existing in a shale stratum, and a high-efficiency plugging layer cannot be formed. The water-based drilling fluid disclosed by the invention contains a plurality of nano materials and micron materials, on one hand, a compact filter cake is formed on a well wall to prevent filtrate from invading a stratum, and on the other hand, nano and micron particle materials enter cracks and pores in a zone close to the well wall to form an inner plugging layer to further prevent the filtrate from entering the stratum and prevent the drilling fluid from acting on the stratum, so that the effect of stabilizing the well wall is achieved.
The invention relates to a preparation method of a water-based drilling fluid for shale. In the aspect of inhibition, the synergistic inhibition effect of potassium salt and polyamine is adopted, so that the inhibition of the shale formation clay hydration by the drilling fluid is improved; in the aspect of plugging capability, granular calcium carbonate with different particle sizes, deformable sulfonated asphalt and fibrous sepiolite are used as plugging materials for plugging cracks and pores with the size of more than micron, and the large pores and the cracks are effectively plugged through the plugging particles with the combination of polymorphous form, rigidity and flexibility, so that a compact plugging layer can be formed; and secondly, materials such as nano paraffin emulsion, nano silicon dioxide and modified graphene oxide are adopted, so that the plugging of a large number of nano cracks and pores in the shale formation is realized, and the plugging agent can participate in the formation of a filter cake of the drilling fluid, so that the filter cake of the drilling fluid is more compact, and the plugging capability of the drilling fluid is further improved. The developed modified graphene oxide is used as a key plugging material, so that the compactness of a filter cake and the plugging capability of a micropore seam are improved, the drilling fluid is effectively prevented from invading a shale stratum, and the filtration loss is low; in the aspects of rheology and lubricity, a compatible flow type regulator and a lubricant are adopted to maintain the rheology and the lubricating property of the drilling fluid; the capability of carrying rock sand is stronger, and the lubricity is better.
The water-based drilling fluid for shale prepared by the invention still has excellent inhibiting and plugging properties under the conditions of shale and mudstone, has the temperature resistance of 80-150 ℃, has good rheological property, filtration wall-building property and lubricity, can meet the horizontal drilling requirement of shale stratum, has stronger technical advantages in the shale gas development field, provides a new technical means for the drilling fluid technology of shale gas exploration and development, and has great significance for promoting the shale gas exploration and development in China.
Detailed Description
The present invention will be further described with reference to the following examples. However, the present invention is not limited to these examples.
The starting materials used in the examples are all commercially available.
Preparing modified graphene oxide:
the preparation method of the modified graphene oxide comprises the following steps:
(1) placing 25g of graphite, 600g of mixed solution of concentrated sulfuric acid and phosphoric acid (weight ratio is 5:1) in a beaker, stirring for 30min to fully mix, and weighing 200g of KMnO4Slowly adding the mixture into a beaker in batches and stirring; after the reaction was complete, the beaker was placed in an ice-water bath and 1500g of distilled water was added to dilute the reaction solution, and 13g H was added in portions2O2Until the reaction product is golden yellow;
(2) then centrifuging the reaction product and washing the reaction product for several times by using distilled water and 10% diluted hydrochloric acid solution until the pH value is neutral; finally, after centrifugal precipitation, the graphite oxide is re-dispersed in water, and stirred for 30min at 10000rpm by a shearing emulsifying stirrer to obtain graphite oxide water dispersion liquid; then, carrying out suction filtration by using a microfiltration membrane with the diameter of 0.45 mu m, and freeze-drying and grinding a filter cake to fine powder with the size of 100 meshes to obtain graphene oxide;
(3) dispersing 2g of graphene oxide in 200g of deionized water, adding 2g of N-methylolacrylamide and 2g of dimethyl diallyl ammonium chloride, introducing nitrogen for 20min, heating to 60 ℃, adding 20g of a solution containing cerium ammonium nitrate as a catalyst (with the concentration of the catalyst being 10%), stirring and reacting for 6h under the condition of introducing nitrogen, and filtering, washing and drying to obtain the modified graphene oxide of the surface graft polymer for later use.
Example 1
Firstly, measuring 300mL of tap water, sequentially adding 6g of drilling bentonite (Hubei Longhai chemical Co., Ltd.) and 0.3g of soda (Sichuan creative energy petroleum engineering technology Co., Ltd., purity 98%) under stirring at 600r/min, stirring for 30min, and then sealing and maintaining for 24 h; under the high-speed stirring of 7000r/min, 10g of filtrate reducer (3g of sodium carboxymethyl cellulose (LV-CMC, produced by Sichuan creative Petroleum engineering Co., Ltd.) and 7g of modified starch (SMART, produced by China petrochemical Petroleum engineering research institute) are added and stirred for 10min, 1g of flow pattern regulator (Xanthan gum XC (Shandong Shunyang-derived Petroleum technology Co., Ltd.) is added and stirred for 10min, 10g of plugging and collapse prevention agent (calcium carbonate (Shandong Shunyang-derived Petroleum technology Co., Ltd., QS-2) and low-softening-point sulfonated asphalt FT-1 (New county seventh chemical plant, FT-1) and sepiolite (Hubei dragon sea Co., Ltd.) are added and stirred for 10min according to the mass ratio of 2:2:1), wherein the calcium carbonate is prepared by mixing superfine calcium carbonate of 200 mesh: 400 mesh 800: 1250 mesh weight: 2:1, adding 10g of nano plugging anti-collapse agent (nano paraffin emulsion, SMSL, nano silicon dioxide, SCLS and modified graphene oxide in a mass ratio of 3:3:2) into the drilling fluid, stirring the mixture for 10min, adding 25g of anti-collapse agent (5g of amino inhibitor polyamine, SMJA-1 and 20g of potassium chloride, 98% purity, BYOYA, Nanyang) into the drilling fluid, stirring the mixture for 20min, adding 2g of potassium hydroxide into the mixture to adjust the pH value to be 8-10, stirring the mixture for 30min, adding 6g of lubricant modified vegetable oil, SMJH-1 into the drilling fluid, and stirring the mixture for 20min to prepare the strong-inhibition strong-plugging water-based drilling fluid suitable for the shale stratum, wherein the density is 1.22g/cm3。
Comparative example 1
The procedure was the same as in example 1 except that modified graphene oxide was not added.
Example 2
First, 300mL of tap water is measured and stirred at 600r/minSequentially adding 6g of drilling bentonite and 0.3g of soda ash, stirring for 30min, and then sealing and maintaining for 24 h; under the high-speed stirring of 7000r/min, adding 10g of fluid loss additive (3g of sodium carboxymethyl cellulose and 7g of modified starch) and stirring for 10min, adding 1g of flow pattern regulator (xanthan gum XC) and stirring for 10min, adding 10g of plugging anti-collapse agent (calcium carbonate, sulfonated asphalt and sepiolite in a mass ratio of 2:2:1) and stirring for 10min, adding 10g of nano plugging anti-collapse agent (nano paraffin emulsion, nano silicon dioxide and modified graphene oxide in a mass ratio of 3:3:2) and stirring for 10min, adding 25g of anti-collapse agent (5g of amine inhibitor polyamine and 20g of potassium chloride) and stirring for 20min, adding 2g of potassium hydroxide and adjusting the pH value to 8-10 and stirring for 30min, adding 6g of lubricant modified vegetable oil and adding 80g of barite powder and stirring for 20min to prepare the strong-inhibition strong-plugging water-based drilling fluid applicable to shale strata, density 1.40g/cm3。
Comparative example 2
The procedure was the same as in example 2 except that modified graphene oxide was not added.
Example 3
Firstly, measuring 300mL of tap water, sequentially adding 5g of drilling bentonite and 0.3g of soda under stirring at 600r/min, stirring for 30min, and then sealing and maintaining for 24 h; under the high-speed stirring of 7000r/min, adding 10g of fluid loss additive (3g of sodium carboxymethyl cellulose and 7g of modified starch) and stirring for 10min, adding 1g of flow pattern regulator (xanthan gum XC) and stirring for 10min, adding 10g of plugging anti-collapse agent (calcium carbonate, sulfonated asphalt and sepiolite in a mass ratio of 2:2:1) and stirring for 10min, adding 10g of nano plugging anti-collapse agent (nano paraffin emulsion, nano silicon dioxide and modified graphene oxide in a mass ratio of 3:3:2) and stirring for 10min, adding 25g of anti-collapse agent (5g of amino inhibitor polyamine and 20g of potassium chloride) and stirring for 20min, adding potassium hydroxide and regulating the pH value to 8-10, stirring for 30min, adding 8g of lubricant modified vegetable oil and 250g of barite powder and stirring for 20min to prepare the strong-inhibition strong-plugging water-based drilling fluid applicable to strata, density 1.70g/cm3。
Comparative example 3
The procedure was the same as in example 3, except that modified graphene oxide was not added.
Example 4
Firstly, measuring 300mL of tap water, sequentially adding 4g of drilling bentonite and 0.2g of soda under stirring at 600r/min, stirring for 30min, and then sealing and maintaining for 24 h; adding 8g of filtrate reducer (3g of sodium carboxymethyl cellulose and 5g of modified starch) and stirring for 10min under 7000r/min high-speed stirring, adding 1g of flow pattern regulator (xanthan gum XC) and stirring for 10min, adding 10g of plugging anti-collapse agent (calcium carbonate, sulfonated asphalt and sepiolite in a mass ratio of 2:2:1) and stirring for 10min, adding 10g of nano plugging anti-collapse agent (nano paraffin emulsion, nano silicon dioxide and modified graphene oxide in a mass ratio of 3:3:2) and stirring for 10min, adding 25g of inhibitor (5g of amine inhibitor polyamine and 20g of potassium chloride) and stirring for 20min, adding potassium hydroxide to adjust the pH value to 8-10, stirring for 30min, adding 10g of lubricant modified vegetable oil, adding 470g of barite powder and stirring for 20min to prepare the strong-inhibition strong-plugging water-based drilling fluid applicable to strata, density 1.99g/cm3。
Comparative example 4
The procedure was the same as in example 4 except that modified graphene oxide was not added.
Effects of the embodiment
The water-based drilling fluid with strong inhibition and strong plugging property and suitable for the shale formation prepared in the examples 1-4 and the drilling fluids prepared in the comparative examples 1-4 are subjected to performance tests. The method for testing the performance of the drilling fluid is carried out according to the following standards that GB/T16783.1 petroleum and natural gas industry drilling fluid tests a first part of water-based drilling fluid (tests PV, YP, API and HTHP), SY/T6094 drilling fluid uses a lubricant evaluation program (tests the extreme pressure lubrication coefficient of the drilling fluid) and SY/T6335 shale inhibitor evaluation method (tests the linear expansion rate). The specific test results are shown in table 1 below.
Table 1 Performance testing of the water-based drilling fluids of examples 1-4 at different temperatures
TABLE 2 comparison of the Properties of examples 1 to 4 and comparative examples 1 to 4
Remarking: the curing temperature was 120 ℃.
Under the maintenance of different temperatures, the rheological property of the drilling fluid is stable, the requirement of drilling on the sand in the rock-carrying zone can be met, the API (application program interface) filtration loss and the HTHP filtration loss are low, the wall building property is good, the data of the linear expansion rate test result is low, the hydration expansion of clay can be well inhibited, and the inhibition property is good. Compared with the comparative example, the API fluid loss, HTHP fluid loss and extreme pressure lubrication coefficient of the example are lower, which shows that the modified graphene oxide can play a better role in plugging and reducing fluid loss and improving the lubricity of the drilling fluid in the example.
Claims (13)
1. A strong-inhibition strong-plugging water-based drilling fluid suitable for a shale formation comprises the following components in parts by weight:
100 parts of water;
1-3 parts of bentonite;
0.5-4 parts of a filtrate reducer;
0-0.7 part of flow pattern regulator;
2.5-5.5 parts of a plugging anti-collapse agent;
0.5-4.5 parts of a nano plugging anti-collapse agent;
4-9 parts of an anti-collapse agent;
1-5 parts of a lubricant;
0-170 parts of density regulator;
the amount of the sodium carbonate is 4-6% of the weight of the bentonite;
the nano plugging anti-collapse agent is a mixture of nano paraffin emulsion, nano silicon dioxide and modified graphene oxide, and the mass ratio of the nano paraffin emulsion to the nano silicon dioxide to the modified graphene oxide is (2.5-3.5) to (1.5-2.5);
the plugging anti-collapse agent is a mixture of sulfonated asphalt, superfine calcium carbonate and sepiolite fiber plugging agent, and the mass ratio of the plugging anti-collapse agent is (1.5-2.5) to (0.5-1.5); wherein the ultrafine calcium carbonate comprises calcium carbonate particles of 200 meshes, 400 meshes, 800 meshes and 1250 meshes; wherein the mass ratio of the calcium carbonate particles with 200 meshes, 400 meshes, 800 meshes and 1250 meshes is (0.5-1.5), (1.5-2.5) and (0.5-1.5); the length of the sepiolite fiber plugging agent is 50-100 mu m;
the anti-collapse agent is a mixture of an amine inhibitor and potassium chloride; the modified graphene oxide is prepared by a method comprising the following steps:
(1) placing graphite and an oxidizing acid solution in a reaction container, and stirring to fully mix the graphite and the oxidizing acid solution; mixing KMnO4Slowly adding the mixture into a reaction container in batches, stirring, placing the reaction container into an ice-water bath after full reaction, and adding water to dilute reaction liquid, wherein the water is selected from distilled water or deionized water; adding hydrogen peroxide in batches until the reaction product is golden yellow;
(2) then centrifuging and washing the reaction product until the pH value is neutral; finally, after centrifugal precipitation, re-dispersing the graphene oxide in water, and stirring to obtain a graphene oxide aqueous dispersion; performing suction filtration, and freeze-drying and grinding a filter cake to obtain graphene oxide;
(3) dispersing graphene oxide in water, wherein the water is selected from distilled water or deionized water; then adding a polymerized monomer A and a polymerized monomer B, introducing nitrogen, heating to 50-70 ℃, then adding a solution containing a catalyst, stirring for reaction under the condition of introducing nitrogen, and filtering, washing and drying to obtain the modified graphene oxide of the surface graft polymer;
in the step (3), the step (c),
the chemical structure of the polymerized monomer A is as follows:
formula (1)
In the formula (1), R1Is hydrogen or C1～C3Hydroxyalkyl groups of (a);
the chemical structure of the polymerized monomer B is as follows:
formula (2)
In the formula (2), R3Is C1～C2Alkyl group of (1).
2. The water-based drilling fluid with strong inhibition and strong plugging properties suitable for the shale formation according to claim 1, is characterized by comprising the following components in parts by weight:
100 parts of water;
1.0-2.5 parts of bentonite;
1.0-4.0 parts of a filtrate reducer;
0.1-0.5 part of flow pattern regulator;
3-5 parts of a plugging anti-collapse agent;
1-4 parts of a nano plugging anti-collapse agent;
5-9 parts of an anti-collapse agent;
2-4 parts of a lubricant;
0-170 parts of density regulator;
the amount of the sodium carbonate is 4-6% of the weight of the bentonite.
3. The strong inhibition and strong plugging water-based drilling fluid suitable for the shale formation according to claim 1 or 2, wherein:
in the step (1), the step (c),
the weight ratio of the graphite to the oxidizing acid solution is 1 (20-40); the oxidizing acid solution is at least one of sulfuric acid, phosphoric acid, nitric acid, nitrous acid, perchloric acid and hypochlorous acid,
the graphite and KMnO4The weight ratio of (1), (6-12);
the hydrogen peroxide and KMnO4The weight ratio of (1) to (14-18).
4. The strong inhibition and strong plugging water-based drilling fluid suitable for the shale formation according to claim 3, wherein:
in the step (1), the step (c),
the oxidizing acid solution is a mixed solution of concentrated sulfuric acid and phosphoric acid.
5. The strong inhibition and strong plugging water-based drilling fluid suitable for the shale formation according to claim 4, wherein:
in the step (1), the step (c),
the oxidizing acid solution is a mixed solution of concentrated sulfuric acid and phosphoric acid, wherein the weight ratio of the concentrated sulfuric acid to the phosphoric acid is (4-7): 1.
6. the strong inhibition and strong plugging water-based drilling fluid suitable for the shale formation according to claim 1 or 2, wherein:
in the step (3), the step (c),
the weight ratio of the graphene oxide to the polymerized monomer A is 1 (0.5-3); the weight ratio of the graphene oxide to the polymerized monomer B is 1 (0.5-3); the weight ratio of the catalyst to the total weight of the polymerized monomer A, B is (0.3-0.6) to 1; the weight concentration of the catalyst in the catalyst solution is 5-12%;
the catalyst is selected from at least one of ammonium cerium nitrate, cerium sulfate and cerium fluoride, or at least one of potassium persulfate, ammonium persulfate and sodium persulfate.
7. The strong inhibition and strong plugging water-based drilling fluid suitable for the shale formation according to claim 6, wherein:
in the step (3), the step (c),
the weight ratio of the graphene oxide to the polymerized monomer A is 1 (1-2);
the weight ratio of the graphene oxide to the polymerized monomer B is 1 (1-2).
8. The strong inhibition and strong plugging water-based drilling fluid suitable for the shale formation according to claim 6, wherein:
in the step (3), the step (c),
the weight concentration of the catalyst in the catalyst solution is 8-10%.
9. The strong inhibition and strong plugging water-based drilling fluid suitable for the shale formation according to claim 1 or 2, wherein:
in the formula (1), R is1Is hydrogen or hydroxymethyl.
10. The strong inhibition and strong plugging water-based drilling fluid suitable for the shale formation according to claim 1 or 2, wherein:
the water-based drilling fluid with strong inhibition and strong plugging properties further comprises a pH value regulator, and the pH value is regulated to 8-10 by the pH value regulator; the pH value regulator is selected from sodium hydroxide and/or potassium hydroxide;
the fluid loss additive is selected from at least one of sodium carboxymethyl cellulose, polyanionic cellulose and modified starch;
the flow pattern regulator is selected from biogums and synthetic polymers.
11. The strong inhibition and strong plugging water-based drilling fluid suitable for the shale formation according to claim 10, wherein:
the pH value regulator is potassium hydroxide.
12. The strong inhibition and strong plugging water-based drilling fluid suitable for the shale formation according to claim 1 or 2, wherein:
the amine inhibitor is selected from at least one of polyamine, polyether amine and amine polyalcohol; wherein, based on 100 parts by weight of water, 0.3-2 parts by weight of the amido inhibitor and 5-7 parts by weight of potassium chloride are added;
the lubricant is selected from at least one of mineral oil modified lubricant, vegetable oil modified lubricant, graphite and water-based lubricant.
13. The preparation method of the strong-inhibition strong-plugging water-based drilling fluid suitable for the shale formation according to any one of claims 1 to 12, characterized by comprising the following steps:
adding the bentonite and the soda ash into water according to the dosage, uniformly stirring, and sealing and maintaining; adding the components including the filtrate reducer, the flow pattern regulator, the plugging and anti-collapse agent, the nano plugging and anti-collapse agent, the anti-collapse inhibitor and the lubricant under high-speed stirring, uniformly stirring, regulating the pH value to 8-10, and adding the density regulator to the required density to obtain the high-density composite material.
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