CN114806535A - Modified nano-silica fluid, preparation method and application thereof, slickwater fracturing fluid and application thereof - Google Patents
Modified nano-silica fluid, preparation method and application thereof, slickwater fracturing fluid and application thereof Download PDFInfo
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- CN114806535A CN114806535A CN202210404396.0A CN202210404396A CN114806535A CN 114806535 A CN114806535 A CN 114806535A CN 202210404396 A CN202210404396 A CN 202210404396A CN 114806535 A CN114806535 A CN 114806535A
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- 239000012530 fluid Substances 0.000 title claims abstract description 133
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N silicon dioxide Inorganic materials O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 title claims abstract description 101
- 239000000377 silicon dioxide Substances 0.000 title claims abstract description 63
- 238000002360 preparation method Methods 0.000 title claims abstract description 26
- 235000012239 silicon dioxide Nutrition 0.000 claims abstract description 20
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 17
- 239000005543 nano-size silicon particle Substances 0.000 claims abstract description 15
- 239000003079 shale oil Substances 0.000 claims abstract description 15
- 238000011161 development Methods 0.000 claims abstract description 10
- 239000003381 stabilizer Substances 0.000 claims description 39
- 229920002401 polyacrylamide Polymers 0.000 claims description 27
- 239000003607 modifier Substances 0.000 claims description 25
- -1 alkyl glucoside Chemical class 0.000 claims description 21
- 239000003638 chemical reducing agent Substances 0.000 claims description 21
- 230000004048 modification Effects 0.000 claims description 19
- 238000012986 modification Methods 0.000 claims description 19
- 125000000217 alkyl group Chemical group 0.000 claims description 15
- 239000000654 additive Substances 0.000 claims description 13
- 230000000996 additive effect Effects 0.000 claims description 13
- 125000002091 cationic group Chemical group 0.000 claims description 12
- 229910052708 sodium Inorganic materials 0.000 claims description 12
- 239000011734 sodium Substances 0.000 claims description 12
- 229920002907 Guar gum Polymers 0.000 claims description 11
- 239000000665 guar gum Substances 0.000 claims description 11
- 229960002154 guar gum Drugs 0.000 claims description 11
- 235000010417 guar gum Nutrition 0.000 claims description 11
- DGAQECJNVWCQMB-PUAWFVPOSA-M Ilexoside XXIX Chemical compound 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 claims description 10
- 229920001577 copolymer Polymers 0.000 claims description 10
- 238000005086 pumping Methods 0.000 claims description 10
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical compound OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 claims description 9
- DNIAPMSPPWPWGF-UHFFFAOYSA-N Propylene glycol Chemical compound CC(O)CO DNIAPMSPPWPWGF-UHFFFAOYSA-N 0.000 claims description 9
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical compound [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 claims description 8
- 239000002994 raw material Substances 0.000 claims description 8
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 claims description 8
- 239000003795 chemical substances by application Substances 0.000 claims description 7
- 238000000034 method Methods 0.000 claims description 7
- 239000002245 particle Substances 0.000 claims description 7
- ZKKHONSNXYFDJC-UHFFFAOYSA-N 1-chloro-7-oxabicyclo[4.1.0]hepta-2,4-diene Chemical compound C1=CC=CC2(Cl)C1O2 ZKKHONSNXYFDJC-UHFFFAOYSA-N 0.000 claims description 6
- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonia chloride Chemical compound [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 claims description 6
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims description 6
- LRHPLDYGYMQRHN-UHFFFAOYSA-N N-Butanol Chemical compound CCCCO LRHPLDYGYMQRHN-UHFFFAOYSA-N 0.000 claims description 6
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 claims description 6
- ZXEKIIBDNHEJCQ-UHFFFAOYSA-N isobutanol Chemical compound CC(C)CO ZXEKIIBDNHEJCQ-UHFFFAOYSA-N 0.000 claims description 6
- 239000000203 mixture Substances 0.000 claims description 6
- PSBDWGZCVUAZQS-UHFFFAOYSA-N (dimethylsulfonio)acetate Chemical compound C[S+](C)CC([O-])=O PSBDWGZCVUAZQS-UHFFFAOYSA-N 0.000 claims description 5
- KWYHDKDOAIKMQN-UHFFFAOYSA-N N,N,N',N'-tetramethylethylenediamine Chemical compound CN(C)CCN(C)C KWYHDKDOAIKMQN-UHFFFAOYSA-N 0.000 claims description 5
- 125000005233 alkylalcohol group Chemical group 0.000 claims description 5
- 229930182478 glucoside Natural products 0.000 claims description 5
- 238000002156 mixing Methods 0.000 claims description 5
- 229940051841 polyoxyethylene ether Drugs 0.000 claims description 5
- 229920000056 polyoxyethylene ether Polymers 0.000 claims description 5
- 229940117986 sulfobetaine Drugs 0.000 claims description 5
- SCYULBFZEHDVBN-UHFFFAOYSA-N 1,1-Dichloroethane Chemical compound CC(Cl)Cl SCYULBFZEHDVBN-UHFFFAOYSA-N 0.000 claims description 4
- KNKRKFALVUDBJE-UHFFFAOYSA-N 1,2-dichloropropane Chemical compound CC(Cl)CCl KNKRKFALVUDBJE-UHFFFAOYSA-N 0.000 claims description 4
- JUXXCHAGQCBNTI-UHFFFAOYSA-N 1-n,1-n,2-n,2-n-tetramethylpropane-1,2-diamine Chemical compound CN(C)C(C)CN(C)C JUXXCHAGQCBNTI-UHFFFAOYSA-N 0.000 claims description 4
- KWIUHFFTVRNATP-UHFFFAOYSA-N Betaine Natural products C[N+](C)(C)CC([O-])=O KWIUHFFTVRNATP-UHFFFAOYSA-N 0.000 claims description 4
- SXRSQZLOMIGNAQ-UHFFFAOYSA-N Glutaraldehyde Chemical compound O=CCCCC=O SXRSQZLOMIGNAQ-UHFFFAOYSA-N 0.000 claims description 4
- 229960003237 betaine Drugs 0.000 claims description 4
- 229920013818 hydroxypropyl guar gum Polymers 0.000 claims description 4
- 229920000371 poly(diallyldimethylammonium chloride) polymer Polymers 0.000 claims description 4
- 239000001103 potassium chloride Substances 0.000 claims description 4
- 235000011164 potassium chloride Nutrition 0.000 claims description 4
- RMAQACBXLXPBSY-UHFFFAOYSA-N silicic acid Chemical compound O[Si](O)(O)O RMAQACBXLXPBSY-UHFFFAOYSA-N 0.000 claims description 4
- 229910052938 sodium sulfate Inorganic materials 0.000 claims description 4
- 235000011152 sodium sulphate Nutrition 0.000 claims description 4
- RYFMWSXOAZQYPI-UHFFFAOYSA-K trisodium phosphate Chemical compound [Na+].[Na+].[Na+].[O-]P([O-])([O-])=O RYFMWSXOAZQYPI-UHFFFAOYSA-K 0.000 claims description 4
- XSQUKJJJFZCRTK-UHFFFAOYSA-N Urea Chemical compound NC(N)=O XSQUKJJJFZCRTK-UHFFFAOYSA-N 0.000 claims description 3
- 235000019270 ammonium chloride Nutrition 0.000 claims description 3
- 239000004202 carbamide Substances 0.000 claims description 3
- 239000011780 sodium chloride Substances 0.000 claims description 3
- 238000011084 recovery Methods 0.000 abstract description 21
- 238000005213 imbibition Methods 0.000 abstract description 19
- 239000003921 oil Substances 0.000 abstract description 12
- 239000011435 rock Substances 0.000 abstract description 6
- 230000007704 transition Effects 0.000 abstract description 6
- 238000009736 wetting Methods 0.000 abstract description 6
- 238000002474 experimental method Methods 0.000 abstract description 4
- 239000010779 crude oil Substances 0.000 abstract description 3
- 230000008859 change Effects 0.000 abstract description 2
- 230000009881 electrostatic interaction Effects 0.000 abstract description 2
- 230000003993 interaction Effects 0.000 abstract description 2
- 238000000926 separation method Methods 0.000 abstract description 2
- 230000000052 comparative effect Effects 0.000 description 18
- 238000003756 stirring Methods 0.000 description 14
- 230000018109 developmental process Effects 0.000 description 7
- 238000006073 displacement reaction Methods 0.000 description 6
- 239000007788 liquid Substances 0.000 description 6
- 230000009467 reduction Effects 0.000 description 6
- 230000000694 effects Effects 0.000 description 5
- 238000005516 engineering process Methods 0.000 description 4
- 238000004458 analytical method Methods 0.000 description 3
- 238000006243 chemical reaction Methods 0.000 description 3
- 238000011156 evaluation Methods 0.000 description 3
- 230000008014 freezing Effects 0.000 description 3
- 238000007710 freezing Methods 0.000 description 3
- 238000010438 heat treatment Methods 0.000 description 3
- 230000007062 hydrolysis Effects 0.000 description 3
- 238000006460 hydrolysis reaction Methods 0.000 description 3
- 238000004519 manufacturing process Methods 0.000 description 3
- 238000005065 mining Methods 0.000 description 3
- 239000000243 solution Substances 0.000 description 3
- RTZKZFJDLAIYFH-UHFFFAOYSA-N Diethyl ether Chemical compound CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 description 2
- 230000002579 anti-swelling effect Effects 0.000 description 2
- 125000004432 carbon atom Chemical group C* 0.000 description 2
- 238000010276 construction Methods 0.000 description 2
- 238000007334 copolymerization reaction Methods 0.000 description 2
- 238000000502 dialysis Methods 0.000 description 2
- 239000008236 heating water Substances 0.000 description 2
- 239000011259 mixed solution Substances 0.000 description 2
- 239000011148 porous material Substances 0.000 description 2
- 230000008569 process Effects 0.000 description 2
- 239000004576 sand Substances 0.000 description 2
- 238000001878 scanning electron micrograph Methods 0.000 description 2
- 239000004094 surface-active agent Substances 0.000 description 2
- 230000009044 synergistic interaction Effects 0.000 description 2
- LDXJRKWFNNFDSA-UHFFFAOYSA-N 2-(2,4,6,7-tetrahydrotriazolo[4,5-c]pyridin-5-yl)-1-[4-[2-[[3-(trifluoromethoxy)phenyl]methylamino]pyrimidin-5-yl]piperazin-1-yl]ethanone Chemical compound C1CN(CC2=NNN=C21)CC(=O)N3CCN(CC3)C4=CN=C(N=C4)NCC5=CC(=CC=C5)OC(F)(F)F LDXJRKWFNNFDSA-UHFFFAOYSA-N 0.000 description 1
- BPINJMQATUWTID-UHFFFAOYSA-N 3,3-dimethylpentane-2,2-diamine Chemical compound CCC(C)(C)C(C)(N)N BPINJMQATUWTID-UHFFFAOYSA-N 0.000 description 1
- KRHIRJLGBOGLNS-UHFFFAOYSA-N 4-chloro-3h-quinazolin-2-one Chemical compound C1=CC=C2C(Cl)=NC(=O)NC2=C1 KRHIRJLGBOGLNS-UHFFFAOYSA-N 0.000 description 1
- 229910019142 PO4 Inorganic materials 0.000 description 1
- 238000005411 Van der Waals force Methods 0.000 description 1
- 238000010521 absorption reaction Methods 0.000 description 1
- 150000008052 alkyl sulfonates Chemical class 0.000 description 1
- 239000011218 binary composite Substances 0.000 description 1
- 230000033558 biomineral tissue development Effects 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 239000006185 dispersion Substances 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
- 230000002708 enhancing effect Effects 0.000 description 1
- 239000007789 gas Substances 0.000 description 1
- 239000001257 hydrogen Substances 0.000 description 1
- 229910052739 hydrogen Inorganic materials 0.000 description 1
- 230000015784 hyperosmotic salinity response Effects 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000011159 matrix material Substances 0.000 description 1
- NBIIXXVUZAFLBC-UHFFFAOYSA-K phosphate Chemical compound [O-]P([O-])([O-])=O NBIIXXVUZAFLBC-UHFFFAOYSA-K 0.000 description 1
- 239000010452 phosphate Substances 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 238000010008 shearing Methods 0.000 description 1
- 229960000776 sodium tetradecyl sulfate Drugs 0.000 description 1
- DAJSVUQLFFJUSX-UHFFFAOYSA-M sodium;dodecane-1-sulfonate Chemical compound [Na+].CCCCCCCCCCCCS([O-])(=O)=O DAJSVUQLFFJUSX-UHFFFAOYSA-M 0.000 description 1
- UPUIQOIQVMNQAP-UHFFFAOYSA-M sodium;tetradecyl sulfate Chemical compound [Na+].CCCCCCCCCCCCCCOS([O-])(=O)=O UPUIQOIQVMNQAP-UHFFFAOYSA-M 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 230000001954 sterilising effect Effects 0.000 description 1
- 238000004659 sterilization and disinfection Methods 0.000 description 1
- 230000001502 supplementing effect Effects 0.000 description 1
- 239000011206 ternary composite Substances 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
- 230000009466 transformation Effects 0.000 description 1
- 239000002918 waste heat Substances 0.000 description 1
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/66—Compositions based on water or polar solvents
- C09K8/665—Compositions based on water or polar solvents containing inorganic compounds
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/66—Compositions based on water or polar solvents
- C09K8/68—Compositions based on water or polar solvents containing organic compounds
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/84—Compositions based on water or polar solvents
- C09K8/845—Compositions based on water or polar solvents containing inorganic compounds
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- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/84—Compositions based on water or polar solvents
- C09K8/86—Compositions based on water or polar solvents containing organic compounds
- C09K8/88—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
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- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/10—Nanoparticle-containing well treatment fluids
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Abstract
The invention provides a modified nano-silica fluid, a preparation method and application thereof, and a slickwater fracturing fluid and application thereof, and belongs to the technical field of shale oil development. The modified nano-silica fluid can enhance the interaction of the modified nano-silica and the slickwater fracturing fluid through electrostatic interaction and other modes, effectively reduce the oil-water interfacial tension and change the wettability. The slickwater fracturing fluid prepared by the modified nano silicon dioxide fluid can form a wedge-shaped structure in an oil-water-rock three-phase contact area, and the generated structure separation pressure peels crude oil from the surface of rock, so that the imbibition recovery rate is improved. The results of the examples show that the imbibition recovery ratio of the modified nano-silica fluid reaches 12 percent at most, the interfacial tension of the modified nano-silica fluid is reduced to 0.11mN/m, the wetting transition reaches 158 degrees at most, and the imbibition recovery ratio reaches 151 degrees in an 8-hour oil drop stripping experiment.
Description
Technical Field
The invention belongs to the technical field of shale oil development, and particularly relates to a modified nano-silica fluid, a preparation method and application thereof, and a slickwater fracturing fluid and application thereof.
Background
Shale oil becomes a hot spot of global exploration and development of unconventional oil and gas resources, and influences the strategic layout of energy resources of various countries. In the development process of shale oil, an imbibition displacement mining technology becomes an important research direction for improving the yield of a single well and prolonging the production validity period, the wettability of a reservoir is changed by adding a surfactant into a well entering fluid, so that the well entering fluid can spontaneously imbibe into a micro-pore channel of matrix rock by means of the driving of capillary force, crude oil is gradually gathered into a large pore channel by oil-water displacement, and the aims of supplementing the formation energy and improving the final recovery ratio are fulfilled.
The slick hydraulic fracturing technology in the dialysis displacement mining technology has become one of the core technologies of shale oil mining due to low cost, small damage to a reservoir and higher proppant fracture conductivity. However, the existing slickwater fracturing fluid mainly comprises a polymer drag reducer, a small amount of cleanup additive and an anti-swelling agent, and still has the problem of low dialysis recovery rate.
Disclosure of Invention
The invention aims to provide a modified nano-silica fluid, a preparation method and application thereof, a slickwater fracturing fluid and application thereof, and the modified nano-silica fluid can improve the recovery ratio of a shale oil reservoir.
The invention provides a modified nano-silica fluid, which comprises the following preparation raw materials:
the mass content of silicon dioxide in the hydrophilic nano silicon dioxide sol is 20-40%;
the modifier comprises one or more of alkyl glucoside, alkyl polyoxyethylene ether, alkyl sodium sulfate, alkyl sodium sulfonate, alpha-alkenyl sodium sulfonate, alkyl alcohol phosphate sodium, alkyl carboxyl betaine and alkyl hydroxypropyl sulfobetaine.
Preferably, the average particle size of the hydrophilic nano silica sol is 8-15 nm.
Preferably, the stabilizer comprises a first low temperature stabilizer and a second low temperature stabilizer; the mass of the first low-temperature stabilizer and the mass of the second low-temperature stabilizer respectively and independently account for 5-15% of the modified nano silicon dioxide fluid;
the first stabilizer comprises one or more of sodium chloride, ammonium chloride and urea;
the second stabilizer comprises one or more of isobutanol, propylene glycol, n-butanol, ethanol, and methanol.
The invention also provides a preparation method of the modified nano-silica fluid, which comprises the following steps: mixing hydrophilic nano-silica sol, a modifier, a low-temperature stabilizer and water for modification to obtain modified nano-silica fluid;
the modification temperature is 70-90 ℃.
The invention also provides application of the modified nano-silica fluid in the scheme or the modified nano-silica fluid prepared by the preparation method in the scheme in shale oil development.
The invention also provides slickwater fracturing fluid which comprises the following components:
the modified nano-silica fluid is the modified nano-silica fluid described in the above scheme or the modified nano-silica fluid prepared by the preparation method described in the above scheme.
Preferably, the drag reducer comprises one or more of polyacrylamide, partially hydrolyzed polyacrylamide, cationic polyacrylamide, amphoteric polyacrylamide, guar gum, cationic modified guar gum and hydroxypropyl guar gum.
Preferably, the multifunctional additive comprises potassium chloride, a copolymer of tetramethylpropylenediamine and dichloropropane, a copolymer of tetramethylethylenediamine and dichloroethane, and a mixture of one or more of polydiallyldimethylammonium chloride and glutaraldehyde and/or chlorobenzene oxide.
The invention also provides application of the slickwater fracturing fluid in the scheme in shale oil development.
Preferably, the application comprises the following steps:
pumping slickwater fracturing fluid into a stratum to form a crack, and pumping a mixture of slickwater fracturing fluid and a propping agent into the stratum to enable the propping agent to prop the crack; then continuously pumping slickwater fracturing fluid, and extruding the proppant in the shaft into the reservoir stratum; and (4) carrying out reverse drainage, and closing the well for 3-28 days.
The invention provides a modified nano-silica fluid, which comprises the following preparation raw materials: 30 wt% of hydrophilic nano silicon dioxide sol; 30 wt% of a modifier; 20-30 wt% of a low-temperature stabilizer; the balance of water; the mass content of silicon dioxide in the hydrophilic nano silicon dioxide sol is 40%; the modifier comprises one or more of alkyl glucoside, alkyl polyoxyethylene ether, alkyl sodium sulfate, alkyl sodium sulfonate, alpha-alkenyl sodium sulfonate, alkyl alcohol phosphate sodium, alkyl carboxyl betaine and alkyl hydroxypropyl sulfobetaine. When the modified nano-silica fluid is used in the slickwater fracturing fluid, the interaction between the modified nano-silica and the slickwater fracturing fluid can be enhanced through electrostatic interaction, van der waals force, hydrogen bonds and other modes, the oil-water interfacial tension is effectively reduced, and the wettability of reservoir rock is changed. The slickwater fracturing fluid prepared by the modified nano silicon dioxide fluid can enrich the characteristics in an oil-water-solid three-phase contact zone, a wedge-shaped structure is formed in the oil-water-rock three-phase contact zone, and the generated structural separation pressure peels off crude oil from the surface of rock, so that the imbibition recovery rate is improved. The results of the examples show that the imbibition recovery ratio of the modified nano-silica fluid reaches 12 percent at most, the interfacial tension of the modified nano-silica fluid is reduced to 0.11mN/m, the wetting transition reaches 158 degrees at most, and the imbibition recovery ratio reaches 151 degrees in an 8-hour oil drop stripping experiment.
The invention provides a slickwater fracturing fluid which has excellent dispersion stability, resistance reducing performance, sand carrying performance and joint forming capability through the synergistic interaction among a modified nano silicon dioxide fluid, a resistance reducing agent and a multifunctional additive. The results of the examples show that the imbibition recovery ratio of the slickwater fracturing fluid provided by the invention is 16.1 percent at most, and the drag reduction ratio is 83.5 percent at most.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings needed to be used in the embodiments will be briefly described below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and it is obvious for those skilled in the art to obtain other drawings without inventive exercise.
FIG. 1 is an SEM image of hydrophilic nano-silica sol used in comparative examples 2 to 3 and examples 1 to 8;
FIG. 2 is an SEM image of a modified nano-silica fluid prepared in comparative example 3;
FIG. 3 is a DLS chart of the hydrophilic nano-silica sol used in comparative examples 2 to 3 and examples 1 to 8 and the modified nano-silica fluid prepared in comparative example 3.
Detailed Description
The invention provides a modified nano-silica fluid, which comprises the following preparation raw materials:
the mass content of silicon dioxide in the hydrophilic nano silicon dioxide sol is 20-40%;
the modifier comprises one or more of alkyl glucoside, alkyl polyoxyethylene ether, alkyl sodium sulfate, alkyl sodium sulfonate, alpha-alkenyl sodium sulfonate, alkyl alcohol phosphate sodium, alkyl carboxyl betaine and alkyl hydroxypropyl sulfobetaine.
The particle size of the modified nano silicon dioxide fluid is preferably 1-100 nm, and more preferably 5-20 nm.
The modified nano-silica fluid provided by the invention comprises 20-40 wt% of hydrophilic nano-silica sol and more preferably 25-35 wt% of preparation raw materials in percentage by mass; the mass content of the silicon dioxide in the hydrophilic nano-silica sol is 20-40 wt%, and more preferably 25-35 wt%. In the invention, the average particle size of the hydrophilic nano-silica sol is preferably 8-15 nm, and more preferably 10-12 nm; the density is preferably 1.28-1.30 g/mL, and more preferably 1.29 g/mL; the pH value is preferably 7 to 11, more preferably 7.5 to 9.5.
The preparation raw materials of the modified nano-silica fluid provided by the invention comprise 20-40 wt% of the modifier, and more preferably 25-35 wt%. In the present invention, the modifier includes one or more of alkyl glucoside, alkyl polyoxyethylene ether, sodium alkyl sulfate, sodium alkyl sulfonate, sodium α -alkenyl sulfonate, sodium alkyl alcohol phosphate, alkyl carboxybetaine, and alkyl hydroxypropyl sulfobetaine, preferably two or more modifiers, and more preferably three modifiers. In the invention, the number of C atoms in the modifier is preferably 12-16, and more preferably 13-15. In the examples of the present invention, a modifier having 12 (e.g., sodium dodecylsulfonate, dodecylhydroxypropylsulfobetaine) and/or 14 (e.g., tetradecylcarboxylbetaine, sodium tetradecylsulfate, tetradecylpolyoxyethylene ether) carbon atoms is specifically selected. The modifier is used for modifying the hydrophilic nano-silica sol to ensure that the hydrophilic nano-silica sol has activity.
The preparation raw materials of the modified nano-silica fluid provided by the invention comprise 10-30 wt% of low-temperature stabilizer. In the present invention, the stabilizer preferably includes a first low temperature stabilizer and a second low temperature stabilizer; the mass of the first low-temperature stabilizer and the mass of the second low-temperature stabilizer respectively and independently account for 5-15% of the modified nano-silica fluid, and the mass of the first low-temperature stabilizer and the mass of the second low-temperature stabilizer are more preferably 8-12 wt%. In the present invention, the first stabilizer preferably includes one or more of sodium chloride, ammonium chloride and urea; the second stabilizer preferably comprises one or more of isobutanol, propylene glycol, n-butanol, ethanol and methanol. In the invention, the first stabilizer is used for lowering the freezing point of the modified nano-silica fluid and preventing the hydrophilic nano-silica sol and the modifier from being separated out at low temperature; the second stabilizer has the functions of lowering the freezing point of the modified nano-silica fluid, reducing the viscosity of the modified nano-silica fluid and enhancing injectability. The low-temperature stabilizer can maintain the uniformity of the system without freezing when the modified nano-silica fluid is stored at the temperature of minus 5 ℃ or above.
The invention also provides a preparation method of the modified nano-silica fluid, which comprises the following steps: mixing hydrophilic nano-silica sol, a modifier, a low-temperature stabilizer and water for modification to obtain modified nano-silica fluid;
the modification temperature is 70-90 ℃.
In the present invention, the mixing of the hydrophilic type nano-silica sol, the modifier, the low-temperature stabilizer, and water preferably includes: heating water to a modification temperature, adding a low-temperature stabilizer into the water during heating, then adding hydrophilic nano-silica sol into the obtained first mixed solution, and then adding a modifier into the obtained second mixed solution.
In the present invention, the mixing is preferably performed under stirring conditions. The hydrophilic nano-silica sol is preferably stirred for 1 hour after being added.
In the invention, the modification temperature is 70-90 ℃, preferably 75-85 ℃; the modification time is preferably 2-5 h, and more preferably 3-4 h. In the present invention, the modification is preferably carried out under stirring conditions. The activity of the modified nano fluid is increased, and the temperature resistance and salt tolerance are enhanced. The temperature of modification is controlled within the above range, the modification effect is optimal and the system is stable after modification. If the temperature is too high or too low, the product properties are unstable and the reaction efficiency is poor.
After the modification is completed, the invention preferably stirs the obtained modified product until the temperature is reduced to room temperature, so as to obtain the modified nano silicon dioxide fluid.
The invention also provides application of the modified nano-silica fluid in the scheme or the modified nano-silica fluid prepared by the preparation method in the scheme in shale oil development.
In the present invention, the application preferably comprises the steps of: pumping the active nano fluid into a stratum blind well for 3-28 days, and then opening the well for production.
In the invention, the shale oil reservoir condition suitable for the modified nano-silica fluid is preferably that the mineralization degree is between 0 and 80000mg/L, and the temperature is preferably between room temperature and 120 ℃.
The invention also provides slickwater fracturing fluid which comprises the following components:
the modified nano-silica fluid is the modified nano-silica fluid described in the above scheme or the modified nano-silica fluid prepared by the preparation method described in the above scheme.
The slickwater fracturing fluid provided by the invention comprises 0.05-0.5 wt% of modified nano silicon dioxide fluid, preferably 0.1-0.4 wt%, and more preferably 0.2-0.3 wt%.
The slickwater fracturing fluid provided by the invention comprises 0.05-0.5 wt% of drag reducer, preferably 0.1-0.4 wt%, and more preferably 0.2-0.3 wt%. The drag reducer of the present invention preferably comprises one or more of polyacrylamide, partially hydrolyzed polyacrylamide, cationic polyacrylamide, amphoteric polyacrylamide, guar gum, cationic modified guar gum and hydroxypropyl guar gum, more preferably amphoteric polyacrylamide. In the invention, the molecular weight of the polyacrylamide is preferably 100-900 ten thousand, the molecular weight of the cationic polyacrylamide is preferably 100-600 ten thousand, the molecular weight of the amphoteric polyacrylamide is preferably 100-500 ten thousand, the degree of hydrolysis of the partially hydrolyzed polyacrylamide is preferably 1-10%, and the molecular weight is preferably 100-700 ten thousand.
When the drag reducer preferably comprises 100-900 ten thousand polyacrylamide, 1-10% of hydrolysis degree, 100-700 ten thousand partially hydrolyzed polyacrylamide and 100-500 ten thousand amphoteric polyacrylamide, the sum of the mass of the 3 drag reducers is not less than 80% of the total mass of the drag reducer.
When the drag reducer preferably comprises cationic polyacrylamide, guar gum, cationic modified guar gum and hydroxypropyl guar gum with the molecular weight of 100-600 ten thousand, the sum of the mass of the 4 drag reducers is not more than 20% of the total mass of the drag reducer.
In the invention, the cationic polyacrylamide with the molecular weight of 100-600 ten thousand and the cationic modified guanidine gum in the drag reducer are not required to be used together with the partially hydrolyzed polyacrylamide with the hydrolysis degree of 1-10% and the molecular weight of 100-700 ten thousand. If used together, will tend to converge and fail.
The slickwater fracturing fluid provided by the invention comprises 0.1-0.5 wt% of multifunctional additive, preferably 0.2-0.4%. In the present invention, the multifunctional additive preferably comprises potassium chloride, a copolymer of tetramethylpropylenediamine and dichloropropane, a copolymer of tetramethylethylenediamine and dichloroethane, and a mixture of one or more of polydiallyldimethylammonium chloride and glutaraldehyde and/or chlorobenzene oxide.
In the present invention, the copolymerization ratio of the tetramethylpropylenediamine to the dichloropropane copolymer is preferably 1: 0.9 to 0.95, more preferably 1: 0.92 to 0.94; the copolymerization ratio of the tetramethylethylenediamine to the dichloroethane copolymer is preferably 1: 0.9 to 0.95, more preferably 1: 0.92 to 0.94.
In the invention, the sum of the weight of one or more of potassium chloride, a copolymer of tetramethylpropanediamine and dichloropropane, a copolymer of tetramethylethylenediamine and dichloroethane, and polydiallyldimethylammonium chloride in the multifunctional additive is preferably 40-60% of the total weight of the multifunctional additive, and the balance is preferably glutaraldehyde and/or chlorobenzene oxide. The chlorobenzene oxide is preferably chlorobenzene oxide or chlorobenzopyrimidinol. The multifunctional additive of the invention has the functions of anti-swelling and sterilization.
The preparation method of the slickwater fracturing fluid has no special requirements, and all the components are directly and uniformly mixed. In the embodiment of the present invention, the following is specifically provided: and adding the modified nano silicon dioxide fluid and the multifunctional additive into water, stirring for 5-10 min, adding the drag reducer, and stirring for 10-35 min to obtain the slickwater fracturing fluid.
Through the synergistic interaction among the drag reducer, the modified nano-silica fluid and the multifunctional additive, the modified nano-silica fracturing fluid has excellent resistance reduction, sand carrying performance and crack forming capability superior to those of the conventional slickwater fracturing fluid, has unique interface activity, can effectively reduce the interface tension, change the wettability and peel oil drops, and has excellent oil seepage, absorption and discharge capabilities.
The invention also provides application of the slickwater fracturing fluid in the scheme in shale oil development. The method of application preferably comprises the steps of:
pumping slickwater fracturing fluid into a stratum to form a crack, and pumping a mixture of slickwater fracturing fluid and a propping agent into the stratum to enable the propping agent to prop the crack; then continuously pumping slickwater fracturing fluid, and extruding the proppant in the shaft into the reservoir stratum; and (4) carrying out reverse drainage, and closing the well for 3-28 days.
The invention has no special requirements on the implementation conditions of each step in the application process, and the implementation conditions known to those skilled in the art can be adopted.
On the premise of meeting the fracturing construction requirement of a shale oil reservoir, the slickwater fracturing fluid system does not need to be reversely arranged after fracturing construction, can fully utilize fracturing energy and fracturing fluid, is directly used for well opening production after being plugged for 3-28 days, is green and environment-friendly, and reduces cost and improves efficiency.
For further illustration of the present invention, the following detailed description of a modified nanosilica fluid and its preparation method and application, a slickwater fracturing fluid and its application provided by the present invention are provided with reference to the drawings and examples, but they should not be construed as limiting the scope of the present invention.
Modified nanosilica fluids
The preparation methods of the modified nano-silica fluids of comparative examples 1 to 3 and examples 1 to 8 include the following steps:
heating water to 80 ℃, adding a first low-temperature stabilizer and the first low-temperature stabilizer into the water during the heating, uniformly stirring, slowly adding the hydrophilic nano-silica sol into a reaction container, continuously stirring for 1h, slowly adding the modifier into the reaction container, stirring for 3h, stopping heating, and continuously stirring by using waste heat until the temperature is cooled to room temperature to obtain the modified nano-silica fluid.
In comparative examples 1 to 3 and examples 1 to 8, the total mass of the modified nano-silica fluid is 100g, and the amount of water is 100g of the total mass of the modified nano-silica fluid-the amount of other components.
The preparation methods of comparative examples 1 to 3 are the same as those of examples 1 to 8, and the used nano silica sol contains 40% of silica, and the hydrophilic nano silica sol has an average particle size of 10 nm; the density was 1.109g/mL and the pH was 9. The different places are shown in table 1.
TABLE 1 preparation raw materials, amounts and modification temperatures for comparative examples 1 to 3 and examples 1 to 8
0.1g of the modified nano-silica fluids of comparative examples 1 to 3 and examples 1 to 8 was added to 99.9g of water, and after stirring uniformly, the particle size distribution was evaluated by a DLS instrument, the oil-water interfacial tension was measured by a rotary drop method, the wetting transformation ability and the oil drop peeling ability were evaluated by a contact angle evaluation device, and the imbibition recovery ratio was evaluated by an imbibition bottle, with the evaluation results shown in table 2.
TABLE 2 Experimental results for comparative examples 1 to 3 and examples 1 to 8
As can be seen from table 2, the interfacial tension, wetting transition property, oil drop stripping property and imbibition recovery ratio of the modified nanofluid are significantly higher than those of the conventional surfactant solution and the unmodified nanofluid.
As can be seen from table 2, when the types and the amounts of the modifier and the low-temperature stabilizer are the same, the higher the modification temperature is, the better the interfacial tension, the wet transition property, the oil drop stripping property and the imbibition recovery rate of the modified nanofluid are.
As can be seen from Table 2, when the types and the addition amounts of the low-temperature stabilizers are the same, and the addition amounts of the modifiers are the same, the interfacial tension, the wetting transition property, the oil drop stripping property, the imbibition recovery rate and the like of the modified nanofluid are evaluated, and the ternary composite modification effect is better than that of the binary composite modification and is better than that of the single modifier.
As can be seen from Table 2, the interfacial tension, wetting transition property, oil drop stripping property and imbibition recovery ratio of the modified nanofluid are better when the types and the addition amount of the low-temperature stabilizer are the same, and when the total addition amount and the types of the modifier are the same, the addition amounts of different modifiers are the same.
The hydrophilic nano-silica sols (SiO before modification) used in comparative examples 2 to 3 and examples 1 to 8 2 ) SEM and DLS analysis was performed, and the results are shown in FIGS. 1 and 3;
the modified nano-silica fluid (modified SiO) prepared in comparative example 3 2 ) SEM and DLS analysis was performed, and the results are shown in FIGS. 2 and 3. As can be seen from the comprehensive analysis of FIGS. 1 to 3, the particle size of the modified nanofluid is about 10 nm.
Slickwater fracturing fluid
Methods of preparing slickwater fracturing fluids of comparative examples 4-15 and examples 9-14:
adding a certain amount of the modified nano-silica fluid prepared in the embodiment into water, stirring, adding the multifunctional additive, stirring, adding a certain amount of the drag reducer, stirring, and preparing an active nano-fluid reinforced slickwater fracturing fluid system with the total amount of 100 g.
The preparation methods of the slickwater fracturing fluids of comparative examples 4-15 and examples 9-14 are different, and the different places are detailed in table 3.
TABLE 3 materials and amounts of slickwater fracturing fluids for comparative examples 4-15 and examples 9-14
Drag reduction rates of the slickwater fracturing fluids of comparative examples 4-15 and examples 9-14 were evaluated at a discharge capacity of 35L/min with a pipe inner diameter of 10 cm. The results of the experiment are shown in table 4.
The slickwater fracturing fluids of comparative examples 4-15 and examples 9-14 were set at 1000s -1 Shearing and breaking the gel for 30min to obtain a gel breaking solution. And evaluating the imbibition recovery ratio of the gel breaking liquid by adopting an imbibition bottle. The results of the experiment are shown in table 4.
TABLE 4 Experimental results for slickwater fracturing fluids comparing 1-12 and examples 1-6
As can be seen from table 4, the active nanofluid-enhanced slickwater fracturing fluid system has better drag reduction rate and imbibition recovery rate compared with the conventional slickwater with the drag reducer added only, and the higher the dosage of the nanofluid, the higher the drag reduction rate and the imbibition recovery rate.
As can be seen from Table 4, the drag reducer is added in an amount too large to reduce drag and imbibition for the same modified nanofluid.
As can be seen from table 4, the amphoteric polyacrylamide has better drag reduction rate and recovery ratio as a drag reducer than polyacrylamide, partially hydrolyzed polyacrylamide, cationic polyacrylamide, guar gum, cationic modified guar gum and hydroxypropyl modified guar gum under the same nano fluid and the same dosage of the drag reducer.
Drainage performance of different system blind wells
A shale oil dynamic displacement evaluation device is adopted to evaluate the dynamic displacement of the modified nano-fluid, the common slickwater gel breaking liquid in the comparative example 17 and the slickwater fracturing fluid gel breaking liquid in the examples 15-18 in different well-closing time, and the preparation method of the gel breaking liquid comprises the following steps: stirring the common slickwater or slickwater fracturing fluid at the rotating speed of 3000 r/min for 5min to obtain the common slickwater gel breaking liquid or slickwater fracturing fluid gel breaking liquid. The results are shown in Table 5.
Table 5 test results for dynamic drainage of modified nanofluids, plain slickwater and slickwater fracturing fluids
As can be seen from table 5, the drainage oil recovery rate of the slickwater fracturing fluid of the active nano fluid is obviously higher than that of the modified nano fluid and slickwater gel breaking fluid; and the displacement oil recovery rate is higher along with the longer well-closing time.
Although the above embodiments have been described in detail, they are only a part of the embodiments of the present invention, not all of the embodiments, and other embodiments can be obtained without inventive step according to the embodiments, and all of the embodiments belong to the protection scope of the present invention.
Claims (10)
1. The modified nano-silica fluid is characterized by comprising the following preparation raw materials:
20-40 wt% of hydrophilic nano silica sol;
20-40 wt% of a modifier;
10-30 wt% of a low-temperature stabilizer;
the balance of water;
the mass content of silicon dioxide in the hydrophilic nano silicon dioxide sol is 20-40%;
the modifier comprises one or more of alkyl glucoside, alkyl polyoxyethylene ether, alkyl sodium sulfate, alkyl sodium sulfonate, alpha-alkenyl sodium sulfonate, alkyl alcohol phosphate sodium, alkyl carboxyl betaine and alkyl hydroxypropyl sulfobetaine.
2. The modified nanosilica fluid of claim 1, wherein the hydrophilic nanosilica sol has an average particle size of from 8 to 15 nm.
3. The modified nanosilica fluid of claim 1, wherein the stabilizer comprises a first low temperature stabilizer and a second low temperature stabilizer; the mass of the first low-temperature stabilizer and the mass of the second low-temperature stabilizer respectively and independently account for 5-15% of the modified nano silicon dioxide fluid;
the first stabilizer comprises one or more of sodium chloride, ammonium chloride and urea;
the second stabilizer comprises one or more of isobutanol, propylene glycol, n-butanol, ethanol, and methanol.
4. A method for preparing the modified nanosilica fluid of any of claims 1 to 3, comprising the steps of: mixing hydrophilic nano-silica sol, a modifier, a low-temperature stabilizer and water for modification to obtain modified nano-silica fluid;
the modification temperature is 70-90 ℃.
5. Use of the modified nanosilica fluid according to any of claims 1 to 3 or the modified nanosilica fluid obtained by the method of claim 4 in shale oil development.
6. The slickwater fracturing fluid is characterized by comprising the following components:
0.05-0.5 wt% of modified nano silicon dioxide fluid;
0.05 to 0.5 wt% of a drag reducer;
0.1-0.5 wt% of multifunctional additive;
the balance of water;
the modified nano-silica fluid is the modified nano-silica fluid described in any one of claims 1 to 3 or the modified nano-silica fluid prepared by the preparation method described in claim 4.
7. The slickwater fracturing fluid of claim 6, wherein the drag reducer comprises one or more of polyacrylamide, partially hydrolyzed polyacrylamide, cationic polyacrylamide, amphoteric polyacrylamide, guar gum, cationic modified guar gum, and hydroxypropyl guar gum.
8. The slickwater fracturing fluid of claim 6 wherein the multifunctional additive comprises a mixture of one or more of potassium chloride, a copolymer of tetramethylpropylenediamine and dichloropropane, a copolymer of tetramethylethylenediamine and dichloroethane, and polydiallyldimethylammonium chloride with glutaraldehyde and/or chlorobenzene oxide.
9. Use of the slickwater fracturing fluid of any one of claims 5 to 8 in shale oil development.
10. The application according to claim 9, characterized in that it comprises the following steps:
pumping slickwater fracturing fluid into a stratum to form a crack, and pumping a mixture of slickwater fracturing fluid and a propping agent into the stratum to enable the propping agent to prop the crack; then continuously pumping slickwater fracturing fluid, and extruding the proppant in the shaft into the reservoir stratum; and (4) carrying out reverse drainage, and closing the well for 3-28 days.
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