CN117106432A - Quick-dissolving ultrahigh-temperature-resistant low-friction-resistance high-density fracturing fluid and preparation method thereof - Google Patents
Quick-dissolving ultrahigh-temperature-resistant low-friction-resistance high-density fracturing fluid and preparation method thereof Download PDFInfo
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- 239000012530 fluid Substances 0.000 title claims abstract description 81
- 238000002360 preparation method Methods 0.000 title abstract description 7
- 229920000642 polymer Polymers 0.000 claims abstract description 51
- 239000002562 thickening agent Substances 0.000 claims abstract description 34
- 239000000725 suspension Substances 0.000 claims abstract description 29
- 239000003431 cross linking reagent Substances 0.000 claims abstract description 18
- 150000003839 salts Chemical class 0.000 claims abstract description 18
- 239000003381 stabilizer Substances 0.000 claims abstract description 9
- 239000000203 mixture Substances 0.000 claims abstract description 7
- JHJLBTNAGRQEKS-UHFFFAOYSA-M sodium bromide Chemical compound [Na+].[Br-] JHJLBTNAGRQEKS-UHFFFAOYSA-M 0.000 claims description 32
- 239000000243 solution Substances 0.000 claims description 32
- 229920002401 polyacrylamide Polymers 0.000 claims description 19
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 claims description 15
- 239000007787 solid Substances 0.000 claims description 15
- 230000007062 hydrolysis Effects 0.000 claims description 14
- 238000006460 hydrolysis reaction Methods 0.000 claims description 14
- 229920002873 Polyethylenimine Polymers 0.000 claims description 13
- 238000003756 stirring Methods 0.000 claims description 13
- TWRXJAOTZQYOKJ-UHFFFAOYSA-L Magnesium chloride Chemical compound [Mg+2].[Cl-].[Cl-] TWRXJAOTZQYOKJ-UHFFFAOYSA-L 0.000 claims description 12
- VWDWKYIASSYTQR-UHFFFAOYSA-N sodium nitrate Chemical compound [Na+].[O-][N+]([O-])=O VWDWKYIASSYTQR-UHFFFAOYSA-N 0.000 claims description 10
- KWYUFKZDYYNOTN-UHFFFAOYSA-M Potassium hydroxide Chemical compound [OH-].[K+] KWYUFKZDYYNOTN-UHFFFAOYSA-M 0.000 claims description 9
- 239000004280 Sodium formate Substances 0.000 claims description 8
- ROOXNKNUYICQNP-UHFFFAOYSA-N ammonium persulfate Chemical compound [NH4+].[NH4+].[O-]S(=O)(=O)OOS([O-])(=O)=O ROOXNKNUYICQNP-UHFFFAOYSA-N 0.000 claims description 8
- HLBBKKJFGFRGMU-UHFFFAOYSA-M sodium formate Chemical compound [Na+].[O-]C=O HLBBKKJFGFRGMU-UHFFFAOYSA-M 0.000 claims description 8
- 235000019254 sodium formate Nutrition 0.000 claims description 8
- QCWXUUIWCKQGHC-UHFFFAOYSA-N Zirconium Chemical compound [Zr] QCWXUUIWCKQGHC-UHFFFAOYSA-N 0.000 claims description 7
- 239000007788 liquid Substances 0.000 claims description 7
- 239000001508 potassium citrate Substances 0.000 claims description 7
- 229960002635 potassium citrate Drugs 0.000 claims description 7
- QEEAPRPFLLJWCF-UHFFFAOYSA-K potassium citrate (anhydrous) Chemical compound [K+].[K+].[K+].[O-]C(=O)CC(O)(CC([O-])=O)C([O-])=O QEEAPRPFLLJWCF-UHFFFAOYSA-K 0.000 claims description 7
- 235000011082 potassium citrates Nutrition 0.000 claims description 7
- XUXNAKZDHHEHPC-UHFFFAOYSA-M sodium bromate Chemical compound [Na+].[O-]Br(=O)=O XUXNAKZDHHEHPC-UHFFFAOYSA-M 0.000 claims description 7
- RYCLIXPGLDDLTM-UHFFFAOYSA-J tetrapotassium;phosphonato phosphate Chemical compound [K+].[K+].[K+].[K+].[O-]P([O-])(=O)OP([O-])([O-])=O RYCLIXPGLDDLTM-UHFFFAOYSA-J 0.000 claims description 7
- 229910052726 zirconium Inorganic materials 0.000 claims description 7
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical compound [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 claims description 6
- 239000007864 aqueous solution Substances 0.000 claims description 6
- 229910001629 magnesium chloride Inorganic materials 0.000 claims description 6
- IOLCXVTUBQKXJR-UHFFFAOYSA-M potassium bromide Chemical compound [K+].[Br-] IOLCXVTUBQKXJR-UHFFFAOYSA-M 0.000 claims description 6
- BWHMMNNQKKPAPP-UHFFFAOYSA-L potassium carbonate Chemical compound [K+].[K+].[O-]C([O-])=O BWHMMNNQKKPAPP-UHFFFAOYSA-L 0.000 claims description 6
- 239000000843 powder Substances 0.000 claims description 6
- 239000012266 salt solution Substances 0.000 claims description 6
- ZOXJGFHDIHLPTG-UHFFFAOYSA-N Boron Chemical compound [B] ZOXJGFHDIHLPTG-UHFFFAOYSA-N 0.000 claims description 5
- HGHPQUIZVKPZEU-UHFFFAOYSA-N boranylidynezirconium Chemical compound [B].[Zr] HGHPQUIZVKPZEU-UHFFFAOYSA-N 0.000 claims description 5
- 229910052796 boron Inorganic materials 0.000 claims description 5
- USHAGKDGDHPEEY-UHFFFAOYSA-L potassium persulfate Chemical compound [K+].[K+].[O-]S(=O)(=O)OOS([O-])(=O)=O USHAGKDGDHPEEY-UHFFFAOYSA-L 0.000 claims description 5
- 239000004317 sodium nitrate Substances 0.000 claims description 5
- 235000010344 sodium nitrate Nutrition 0.000 claims description 5
- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 claims description 4
- 229910001870 ammonium persulfate Inorganic materials 0.000 claims description 4
- 239000001110 calcium chloride Substances 0.000 claims description 4
- 229910001628 calcium chloride Inorganic materials 0.000 claims description 4
- 239000006185 dispersion Substances 0.000 claims description 4
- 238000000034 method Methods 0.000 claims description 4
- 239000001509 sodium citrate Substances 0.000 claims description 4
- NLJMYIDDQXHKNR-UHFFFAOYSA-K sodium citrate Chemical compound O.O.[Na+].[Na+].[Na+].[O-]C(=O)CC(O)(CC([O-])=O)C([O-])=O NLJMYIDDQXHKNR-UHFFFAOYSA-K 0.000 claims description 4
- ZPWVASYFFYYZEW-UHFFFAOYSA-L dipotassium hydrogen phosphate Chemical compound [K+].[K+].OP([O-])([O-])=O ZPWVASYFFYYZEW-UHFFFAOYSA-L 0.000 claims description 3
- 229920001519 homopolymer Polymers 0.000 claims description 3
- 229910000027 potassium carbonate Inorganic materials 0.000 claims description 3
- 229910000029 sodium carbonate Inorganic materials 0.000 claims description 3
- 235000011083 sodium citrates Nutrition 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
- 239000013522 chelant Substances 0.000 claims description 2
- 229910000402 monopotassium phosphate Inorganic materials 0.000 claims description 2
- 235000019796 monopotassium phosphate Nutrition 0.000 claims description 2
- PJNZPQUBCPKICU-UHFFFAOYSA-N phosphoric acid;potassium Chemical compound [K].OP(O)(O)=O PJNZPQUBCPKICU-UHFFFAOYSA-N 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
- 239000003002 pH adjusting agent Substances 0.000 claims 1
- 230000009467 reduction Effects 0.000 abstract description 13
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 abstract description 13
- 238000004090 dissolution Methods 0.000 abstract description 8
- 239000000126 substance Substances 0.000 abstract description 2
- 230000000694 effects Effects 0.000 abstract 1
- 230000001105 regulatory effect Effects 0.000 abstract 1
- WFIZEGIEIOHZCP-UHFFFAOYSA-M potassium formate Chemical compound [K+].[O-]C=O WFIZEGIEIOHZCP-UHFFFAOYSA-M 0.000 description 20
- 238000005303 weighing Methods 0.000 description 20
- 238000012360 testing method Methods 0.000 description 13
- 238000010276 construction Methods 0.000 description 10
- 239000008367 deionised water Substances 0.000 description 10
- 229910021641 deionized water Inorganic materials 0.000 description 10
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 8
- 238000011056 performance test Methods 0.000 description 8
- ZRALSGWEFCBTJO-UHFFFAOYSA-N Guanidine Chemical compound NC(N)=N ZRALSGWEFCBTJO-UHFFFAOYSA-N 0.000 description 6
- 229960002337 magnesium chloride Drugs 0.000 description 5
- 239000003921 oil Substances 0.000 description 5
- 239000002245 particle Substances 0.000 description 5
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical compound [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 description 4
- 239000007789 gas Substances 0.000 description 4
- 230000002706 hydrostatic effect Effects 0.000 description 4
- 239000003345 natural gas Substances 0.000 description 4
- 239000003209 petroleum derivative Substances 0.000 description 4
- 238000010008 shearing Methods 0.000 description 4
- CHJJGSNFBQVOTG-UHFFFAOYSA-N N-methyl-guanidine Natural products CNC(N)=N CHJJGSNFBQVOTG-UHFFFAOYSA-N 0.000 description 3
- 230000015572 biosynthetic process Effects 0.000 description 3
- 239000003795 chemical substances by application Substances 0.000 description 3
- SWSQBOPZIKWTGO-UHFFFAOYSA-N dimethylaminoamidine Natural products CN(C)C(N)=N SWSQBOPZIKWTGO-UHFFFAOYSA-N 0.000 description 3
- 239000000178 monomer Substances 0.000 description 3
- HRPVXLWXLXDGHG-UHFFFAOYSA-N Acrylamide Chemical compound NC(=O)C=C HRPVXLWXLXDGHG-UHFFFAOYSA-N 0.000 description 2
- BDAGIHXWWSANSR-UHFFFAOYSA-M Formate Chemical compound [O-]C=O BDAGIHXWWSANSR-UHFFFAOYSA-M 0.000 description 2
- 125000000129 anionic group Chemical group 0.000 description 2
- TZCXTZWJZNENPQ-UHFFFAOYSA-L barium sulfate Chemical compound [Ba+2].[O-]S([O-])(=O)=O TZCXTZWJZNENPQ-UHFFFAOYSA-L 0.000 description 2
- ATZQZZAXOPPAAQ-UHFFFAOYSA-M caesium formate Chemical compound [Cs+].[O-]C=O ATZQZZAXOPPAAQ-UHFFFAOYSA-M 0.000 description 2
- 230000000052 comparative effect Effects 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 230000035699 permeability Effects 0.000 description 2
- 239000001103 potassium chloride Substances 0.000 description 2
- 235000011164 potassium chloride Nutrition 0.000 description 2
- 241000251468 Actinopterygii Species 0.000 description 1
- 239000004971 Cross linker Substances 0.000 description 1
- 229920002907 Guar gum Polymers 0.000 description 1
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 1
- 238000004458 analytical method Methods 0.000 description 1
- -1 and the like Substances 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- 125000002091 cationic group Chemical group 0.000 description 1
- 239000000084 colloidal system Substances 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 238000009472 formulation Methods 0.000 description 1
- 239000000665 guar gum Substances 0.000 description 1
- 229960002154 guar gum Drugs 0.000 description 1
- 235000010417 guar gum Nutrition 0.000 description 1
- 238000009776 industrial production Methods 0.000 description 1
- 229910017053 inorganic salt Inorganic materials 0.000 description 1
- 230000003993 interaction Effects 0.000 description 1
- 150000002500 ions Chemical class 0.000 description 1
- 231100000053 low toxicity Toxicity 0.000 description 1
- 229940050906 magnesium chloride hexahydrate Drugs 0.000 description 1
- DHRRIBDTHFBPNG-UHFFFAOYSA-L magnesium dichloride hexahydrate Chemical compound O.O.O.O.O.O.[Mg+2].[Cl-].[Cl-] DHRRIBDTHFBPNG-UHFFFAOYSA-L 0.000 description 1
- 239000002480 mineral oil Substances 0.000 description 1
- 235000010446 mineral oil Nutrition 0.000 description 1
- 239000002105 nanoparticle Substances 0.000 description 1
- 238000006116 polymerization reaction Methods 0.000 description 1
- GNSKLFRGEWLPPA-UHFFFAOYSA-M potassium dihydrogen phosphate Chemical compound [K+].OP(O)([O-])=O GNSKLFRGEWLPPA-UHFFFAOYSA-M 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 238000002407 reforming Methods 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 239000011780 sodium chloride Substances 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
- 239000002904 solvent Substances 0.000 description 1
- 229920001059 synthetic polymer Polymers 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
- C09K8/68—Compositions based on water or polar solvents containing organic compounds
- C09K8/685—Compositions based on water or polar solvents containing organic compounds containing cross-linking agents
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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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- 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
- C09K8/882—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained by reactions only involving carbon-to-carbon unsaturated bonds
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- 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
- C09K8/86—Compositions based on water or polar solvents containing organic compounds
- C09K8/88—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/887—Compositions based on water or polar solvents containing organic compounds macromolecular compounds containing cross-linking agents
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- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/28—Friction or drag reducing additives
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- General Life Sciences & Earth Sciences (AREA)
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- Materials Engineering (AREA)
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Abstract
The invention discloses an instant and ultra-high temperature resistant low friction resistance high density fracturing fluid and a preparation method thereof, and belongs to the technical field of oilfield chemical polymer compositions. The fracturing fluid comprises, by mass, 1.0-4.0 parts of a thickener suspension, 20-70 parts of weighting salt, 0.1-1.0 parts of a cross-linking agent, 0.01-0.1 parts of a high-temperature stabilizer, 0-0.2 parts of a pH value regulator, 0.1-0.5 parts of a gel breaker and the balance of water. The high-temperature-resistant low-friction high-density fracturing fluid can realize density of 1.20-1.50 g/cm by adjusting the proportion of weighting salt and water in the formula 3 The range is regulated and controlled, the operation is simple, and the control is easy; the high-temperature-resistant high-pressure fracturing fluid has excellent temperature resistance and drag reduction effect, the temperature resistance reaches 200 ℃, the drag reduction rate reaches 65%, and simultaneously meets the requirements of quick dissolution, high density, high temperature resistance and low friction resistance performance indexes, and can be used for fracturing high-temperature and high-pressure reservoirsAnd (5) reconstruction.
Description
Technical Field
The invention belongs to the technical field of oilfield chemical polymer compositions, and particularly relates to an instant and ultrahigh-temperature-resistant low-friction high-density fracturing fluid and a preparation method thereof.
Background
In recent years, unconventional reservoirs such as hypotonic reservoirs, high temperature reservoirs and high pressure reservoirs are the main targets for oil and gas exploration and development. Hydraulic fracturing technology is the most effective means for reforming and increasing production of unconventional oil reservoirs, however, high-temperature and high-pressure reservoirs have the problem of too high construction pressure, and conventional fracturing fluid is difficult to meet construction requirements. For example, the depth of a reservoir layer of a Xinjiang Tahe oil field reaches 7000 m, the ground construction pressure of a part of a well operated by using conventional fracturing fluid exceeds 140 MPa, and the rated withstand voltage of the current domestic ground fracturing equipment is about 105 MPa. Thus, reducing equipment construction pressure is an effective means of improving fracture success rate. In the actual construction process, the wellhead construction pressure (P S ) Fracture pressure (P) with formation B ) Fracturing fluid friction (P) f ) And fracturing hydrostatic column pressure (P) H ) The following formula is satisfied:
P S = P B + P f - P H （1）
as can be seen from the formula, the wellhead construction pressure can be reduced by reducing the formation fracture pressure and the fracturing fluid friction or increasing the fracturing fluid hydrostatic column pressure. Because the formation fracture pressure is related to the geological conditions of the reservoir, the fracture pressure can hardly be changed, and therefore, the fracture fluid friction P can only be reduced f And/or increasing fracturing hydrostatic column pressure P H To reduce the wellhead construction pressure P S . The hydrostatic column pressure of the fracturing fluid, the well depth and the density of the fracturing fluid meet the following formulas:
P H = 9.81 ×ρh/1000 （2）
wherein the method comprises the steps ofρIs the density (g/cm) of the fracturing fluid 3 ) H is the well depth length (m). As can be seen from the combination of (1) and (2), the frac fluid density increased by 0.1 g/cm for a deep well of 5000 m 3 The construction pressure is reduced by 5 MPa.
The method for improving the density of the fracturing fluid is mainly to add a weighting agent into the fracturing fluid, and at present, the types of the weighting agent mainly comprise three types: one is an inorganic salt, such as one or a mixture of potassium chloride, sodium bromide, sodium nitrate. Hou Fan, chou Yunan et al journal of oilfield chemistry (2018)12 months, 35 volume, 4 th phase, pages 618-621) a high density fracturing fluid system using potassium chloride as a weighting salt and polyacrylamide compounds as a thickener was reported. The weight density of the system was 1.1 g/cm 3 The temperature resistance reaches 180 ℃, and the resistance reduction rate reaches more than 60%. Zhao Ying describes a high-density fracturing fluid system using sodium nitrate as a weighting salt and a synthetic polymer as a thickening agent in journal of progress of fine petrochemical industry (12 months of 2020, volume 21, 6, pages 1-4). The density of the system was 1.31 g/cm 3 The temperature resistance reaches 180 ℃, and the resistance reduction rate reaches 55.34%. CN113563507a discloses a high density fracturing fluid system using calcium chloride as a weighting salt and anionic polyacrylamide as a thickener. The thickener in the system is formed by copolymerizing an acrylamide monomer, an anionic monomer, a cationic monomer and a nonionic monomer. The patent states that the polymer has the temperature resistance up to 180 ℃, resists divalent ions with high concentration, and can be used for fracturing and increasing production of three ultra-low oil and gas reservoirs. The second category is organic salts, including sodium formate, potassium formate, cesium formate, sodium citrate, and the like, or mixtures of organic and inorganic salts. CN113355078A discloses a high-temperature-resistant high-density fracturing fluid system using potassium formate as a weighting salt and guanidine gum as a thickener, which states that the density of the fracturing fluid can reach 1.6 g/cm 3 . CN102876314a discloses a high density fracturing fluid using formate as weighting agent and guanidine gum as thickener. The formate used comprises one or a mixture of potassium formate, sodium formate and cesium formate. The density of the fracturing fluid can be 1.05-2.3 g/cm by adjusting the proportion of the weighting salt 3 Adjustable in scope. The high-density fracturing fluid has the characteristics of low toxicity, low corrosion and the like, and has the temperature resistance reaching 120 ℃. The third class is solid particles. Tang Ruijiang et al report in J (3.2015, 37, 2 nd, 82-84 pages) a heavy fracturing fluid system using nano barium sulfate as heavy particles and guar gum as a thickening agent. After 70 g nano particles are added into 100 g base solution, the density reaches 1.5 g/cm 3 And the compatibility of the weighting base liquid and the guanidine colloid system is good. The fracturing fluid system has the temperature resistance reaching 120 ℃ and the damage rate to the rock core being less than 30%.
Through analysis of the above documents, although some high-density fracturing fluid systems can reach higher density, the temperature resistance and resistance reduction performance of the systems are poor; some systems can resist high temperature, but have low weighting density, are not suitable for high-pressure and deep reservoir reconstruction, and the fracturing fluid capable of simultaneously meeting the requirements of high temperature resistance, high density and low friction resistance is not reported. In addition, in order to facilitate on-site liquid preparation and simplify the operation flow, an instant type fracturing fluid system is needed, but the instant type high-density fracturing fluid is not reported at present.
Disclosure of Invention
Aiming at the problem that the current weight fracturing fluid system is difficult to meet the performance indexes of high density, high temperature resistance and low friction resistance at the same time, the invention provides an instant and ultra-high temperature resistant low friction resistance high density fracturing fluid and a preparation method thereof, which can obtain the fracturing fluid which meets the requirements of high density, high temperature resistance and low friction resistance at the same time and can be instant, so as to reduce the wellhead construction pressure and meet the requirements of oil and gas exploration reconstruction and yield increase of unconventional reservoirs such as low permeability, high temperature and high pressure.
The invention uses one or more of calcium chloride, magnesium chloride, sodium bromide, potassium bromide, sodium nitrate, sodium formate, potassium citrate, sodium citrate, dipotassium hydrogen phosphate, monopotassium hydrogen phosphate and potassium pyrophosphate as weighting salt, polyacrylamide copolymer or homopolymer as thickening agent, organic zirconium, organic boron or organic boron zirconium as cross-linking agent, and polyethyleneimine as high temperature stabilizer. According to the content of the weighting salt, the density of the fracturing fluid can reach 1.20-1.50 g/cm 3 . The high-density fracturing fluid system provided by the invention has the highest temperature resistance up to 200 ℃ and the resistance reduction rate up to 65%.
The invention provides an instant and ultra-high temperature resistant low friction high density fracturing fluid, which comprises the following components in parts by weight: 100 parts by mass of weighting salt solution, 1.0-4.0 parts by mass of thickening agent suspension, 0-0.2 parts by mass of pH value regulator, 0.1-1.0 parts by mass of cross-linking agent, 0.01-0.1 parts by mass of high-temperature stabilizer and 0.1-0.5 parts by mass of gel breaker; the density of the weighted salt solution is 1.20-1.50 g/cm 3 Wherein the mass concentration of the salt is 20-70%; polymerization of the thickener suspensionThe mass content is 30-40%.
Further, the aggravating salt is one or more of calcium chloride, magnesium chloride, sodium bromide, potassium bromide, sodium nitrate, sodium formate, potassium citrate, sodium citrate, dipotassium hydrogen phosphate, potassium dihydrogen phosphate and potassium pyrophosphate.
Further, the thickener suspension is a polymer suspension, the polymer is a polyacrylamide copolymer or a polyacrylamide homopolymer, preferably ultrahigh molecular weight linear partially hydrolyzed polyacrylamide, the viscosity average molecular weight is 2000-3000 ten thousand, and the degree of hydrolysis is preferably 15-35%.
Further, the polymer suspension is obtained by dispersing the polymer powder in a dispersion liquid, wherein the dispersion liquid is selected from a liquid such as mineral oil with a certain viscosity, and the liquid can disperse and suspend the polymer powder to form a uniform and stable suspension.
Further, the cross-linking agent is one of an organic zirconium aqueous solution, an organic boron aqueous solution or an organic boron zirconium chelate aqueous solution, and the solid content of the solution is 24-26%.
Further, the high-temperature stabilizer is polyethyleneimine, and preferably has a viscosity average molecular weight of 300-10000.
Further, the pH regulator is one of sodium hydroxide, potassium hydroxide, sodium carbonate and potassium carbonate.
Further, the breaker is at least one of ammonium persulfate, potassium persulfate, sodium persulfate and sodium bromate.
The invention also provides a preparation method of the instant ultrahigh-temperature-resistant low-friction high-density fracturing fluid, which comprises the following steps: adding a polymer suspension into a weighted salt solution with a proportioning amount, and stirring until the polymer is completely dissolved; then adding the cross-linking agent, the pH value regulator, the high-temperature stabilizer and the gel breaker, and uniformly stirring.
Compared with the prior art, the invention has the following beneficial effects and characteristics:
1. meanwhile, the performances of ultrahigh temperature resistance, high density and low friction resistance are realized. In the prior art, no technology is known about the realization of high temperature resistance, high density and low friction resistance at the same timeIs reported for the formulation of the weighting fracturing fluid. According to the invention, the ultra-high molecular weight linear partially hydrolyzed polyacrylamide (with the hydrolysis degree of 15-35%) is selected as the thickening agent, and the proper thickening agent, the cross-linking agent, the high-temperature resistant stabilizer, the weighting salt and the proportion design thereof are combined, so that the fracturing fluid system can keep good temperature resistance and salt resistance, and also has excellent resistance reduction performance in high-density saline. The density of the fracturing fluid obtained by the invention is 1.50 g/cm 3 Meanwhile, the temperature resistance reaches 200 ℃, the resistivity of the fracturing fluid reaches 65%, the performance requirements of high temperature resistance, high density and low friction resistance are simultaneously met, and the application requirements of unconventional reservoir oil-gas exploration reconstruction and yield increase of low permeability, high temperature and high pressure can be met.
2. The dissolution time of the thickener is shortened. In high-concentration brine, the dissolution rate of the powdery thickener is low and the powdery thickener is easy to agglomerate to form fish eyes, so that the thickener utilization rate is low. The thickener is prepared into suspension, the aim of instant dissolution is achieved by destroying the interaction among solid particles and increasing the contact area of the thickener particles and the solvent, and the dissolution time of the thickener is greatly shortened.
3. The invention has simple formula, convenient operation and low cost, and is suitable for industrial production.
Drawings
FIG. 1 is a photograph of a polymer suspension (FIG. 1 a) and a polymer powder (FIG. 1 b) after dissolution in a potassium formate solution for 10 min.
FIG. 2 shows the results of the high temperature shear performance test of the sample of example 1 (30-160 ℃,170 s) -1 ）。
FIG. 3 shows the results of the high temperature shear performance test in example 13 (30-150 ℃,170 s) -1 ）。
FIG. 4 shows the results of the high temperature shear performance test of the sample of example 2 (30-160 ℃,170 s) -1 ）。
FIG. 5 shows the results of the high temperature shear performance test of the sample of example 3 (30-200deg.C, 170 s) -1 ）。
FIG. 6 is a graph of drag reduction performance test results for the sample of example 1 at different flow rates.
FIG. 7 is a graph of drag reduction performance test results for the sample of example 2 at different flow rates.
FIG. 8 is a graph of drag reduction performance test results for samples of example 4 at different flow rates.
Detailed Description
The following describes the invention further with reference to specific examples. The following examples are only for more clearly illustrating the technical aspects of the present invention, and are not intended to limit the scope of the present invention.
Example 1
(1) Preparing a high-density potassium formate solution: weighing potassium formate 90 g, weighing deionized water 60 mL, adding into 200 mL beaker, stirring until the solid is completely dissolved to obtain a density of 1.41 g/cm at room temperature 3 Potassium formate solution of (a). (2) Taking a potassium formate solution 100 g, and adding a partially hydrolyzed polyacrylamide suspension (with a molecular weight of 2500 ten thousand and a degree of hydrolysis of 25%) with an effective polymer content of 2.0 g (the mass content of the polymer) of 30%; after the polymer was completely dissolved, 0.2. 0.2 g organozirconium crosslinker solution (solids content 25%, the same as in the examples below), 0.05. 0.05 g polyethylenimine and ammonium persulfate 0.1. 0.1 g were added to give a fracturing fluid with a thickener mass concentration of 0.59%.
Example 2
(1) Preparing a high-density sodium bromide solution: weighing sodium bromide 63 g, weighing deionized water 87 mL, adding into 200 mL beaker, stirring until the solid is completely dissolved to obtain a density of 1.43 g/cm at room temperature 3 Sodium bromide solution of (a). (2) Taking sodium bromide solution 100 g, adding a partially hydrolyzed polyacrylamide suspension with the effective content of 2.0 g and the polymer content of 30 percent (the molecular weight is 2500 ten thousand, and the hydrolysis degree is 25 percent); after the polymer is completely dissolved, adding 0.2 g organic zirconium cross-linking agent solution, 0.01 g sodium hydroxide, 0.04 g polyethyleneimine and 0.1 g sodium bromate to obtain the fracturing fluid with the mass concentration of the thickening agent of 0.59 percent.
Example 3
(1) Preparing a high-density potassium formate solution: weighing potassium formate 90 g, weighing deionized water 60 mL, adding into a beaker of 200 mL, and stirring until solid is obtainedCompletely dissolved to obtain a density of 1.41 g/cm at room temperature 3 Potassium formate solution of (a). (2) Taking 100. 100 g parts of potassium formate solution, and adding a partially hydrolyzed polyacrylamide suspension (with a molecular weight of 2500 ten thousand and a degree of hydrolysis of 25%) with an effective content of 40% of 2.0 g polymers; after the polymer is completely dissolved, adding 0.2 g organic zirconium cross-linking agent solution, 0.04 g polyethyleneimine and 0.5 g potassium persulfate to obtain the fracturing fluid with the mass concentration of the thickening agent of 0.78%.
Example 4
(1) Preparing a high-density sodium bromide solution: weighing sodium bromide 63 g, weighing deionized water 87 mL, adding into 200 mL beaker, stirring until the solid is completely dissolved to obtain a density of 1.43 g/cm at room temperature 3 Sodium bromide solution of (a). (2) Taking sodium bromide solution 100 g, adding a partially hydrolyzed polyacrylamide suspension (with a molecular weight of 2000 ten thousand and a degree of hydrolysis of 30%) with an effective polymer content of 4.0 g; after the polymer is completely dissolved, adding 1.0 g organic boron zirconium cross-linking agent solution, 0.2 g sodium hydroxide, 0.1 g polyethyleneimine and 0.5 g sodium bromate to obtain the fracturing fluid with the mass concentration of the thickening agent of 1.13 percent.
Example 5
(1) Preparing a high-density potassium pyrophosphate solution: weighing potassium pyrophosphate 90 g, weighing deionized water 120 mL, adding into 200 mL beaker, stirring until the solid is completely dissolved to obtain a density of 1.40 g/cm at room temperature 3 Potassium pyrophosphate solution of (2). (2) Taking a potassium pyrophosphate solution of 100 g, and adding a partially hydrolyzed polyacrylamide suspension (with a molecular weight of 3000 ten thousand and a degree of hydrolysis of 15%) with an effective content of 40% of a polymer of 1.0 g; after the polymer is completely dissolved, adding 0.1 g organic boron crosslinking agent solution, 0.04 g polyethyleneimine, 0.01 g potassium hydroxide and 0.5 g potassium persulfate to obtain the fracturing fluid with the mass concentration of the thickening agent of 0.39%.
Example 6
(1) Preparing a high-density sodium bromide solution: weighing sodium bromide 100 g, weighing deionized water 100 mL, adding into 200 mL beaker, stirring until the solid is completely dissolved to obtain a density of 1.50 g/cm at room temperature 3 Sodium bromide solution of (a). (2) Taking sodium bromide solution 100 g, adding 1.0 g part of water with 40% of the effective content of polymerDepolymerizing the acrylamide suspension (molecular weight 3000 ten thousand, degree of hydrolysis 35%); after the polymer is completely dissolved, adding 0.5 g organic boron zirconium cross-linking agent solution, 0.01 g sodium carbonate, 0.01 g polyethyleneimine and 0.2 g sodium bromate to obtain the fracturing fluid with the mass concentration of the thickening agent of 0.39 percent.
Example 7
(1) Preparing a high-density potassium formate solution: weighing potassium formate 230 g, weighing deionized water 100 mL, adding into 200 mL beaker, stirring until the solid is completely dissolved to obtain a density of 1.50 g/cm at room temperature 3 Potassium formate solution of (a). (2) Taking a potassium formate solution of 100 g, and adding a partially hydrolyzed polyacrylamide suspension (with a molecular weight of 2000 ten thousand and a degree of hydrolysis of 15%) with an effective content of 40% of 2.0 g polymer; after the polymer is completely dissolved, adding 0.2 g organic zirconium cross-linking agent solution, 0.01 g sodium hydroxide, 0.05 g polyethyleneimine and 0.5 g sodium bromate to obtain the fracturing fluid with the mass concentration of the thickening agent of 0.78 percent.
Example 8
(1) Preparing a high-density magnesium chloride solution: weighing magnesium chloride hexahydrate 110 g, weighing deionized water 110 mL, adding into 200 mL beaker, stirring until the solid is completely dissolved to obtain a density of 1.21 g/cm at room temperature 3 Magnesium chloride solution of (a). (2) Taking 100 percent g of magnesium chloride solution, and adding a partially hydrolyzed polyacrylamide copolymer suspension (with a molecular weight of 2500 ten thousand and a degree of hydrolysis of 25 percent) with an effective polymer content of 40 percent of 1.0 percent g; after the polymer is completely dissolved, adding 0.2 g organic boron crosslinking agent solution, 0.04 g polyethyleneimine and 0.1 g ammonium persulfate to obtain the fracturing fluid with the mass concentration of the thickening agent of 0.39%.
Example 9
(1) Preparing a high-density sodium formate solution: weighing sodium formate 50 g, weighing deionized water 110 mL, adding into 200 mL beaker, stirring until the solid is completely dissolved to obtain a density of 1.21 g/cm at room temperature 3 Potassium formate solution of (a). (2) Taking sodium formate solution 100 g, adding a partially hydrolyzed polyacrylamide suspension (molecular weight 2500 ten thousand, degree of hydrolysis 25%) with an effective polymer content of 30% of 4.0 g; after the polymer is completely dissolved, 0.2 g organozirconium cross-linking agent solution, 0.02 g polyethylenimine and0.5 And g sodium bromate to obtain the fracturing fluid with the mass concentration of the thickening agent of 1.15%.
Example 10
(1) Preparing a high-density potassium citrate solution: weighing potassium citrate 90 g, weighing deionized water 120 mL, adding into 200 mL beaker, stirring until the solid is completely dissolved to obtain a density of 1.31 g/cm at room temperature 3 Potassium citrate of (a) and a salt thereof. (2) Taking a potassium citrate solution of 100 g, and adding a partially hydrolyzed polyacrylamide suspension (with a molecular weight of 2500 ten thousand and a degree of hydrolysis of 25%) with an effective content of 40% of 1.5 g polymer; after the polymer is completely dissolved, adding 0.2 g organic zirconium cross-linking agent solution, 0.02 g polyethyleneimine, 0.1 g potassium carbonate and 0.5 g potassium persulfate to obtain the fracturing fluid with the mass concentration of the thickening agent of 0.59 percent.
Example 11
Instant performance test of example 1: (1) Adding a 50 g potassium formate solution prepared in advance into a 100 mL beaker; (2) 2.0 g of the polymer suspension was added to the beaker in (1) while an equal amount of polymer was added to another 50 g potassium formate solution as a comparison, stirred and started to time, and the time required for complete dissolution of the polymer was observed. The results are shown in FIG. 1. The polymer suspension was completely dissolved after 10 min in the high density potassium formate solution (fig. 1 a), while the polymer powder remained undissolved particles after 10 min (fig. 1 b), indicating a faster dissolution rate of the polymer suspension.
Example 12
The samples of example 1 were subjected to a temperature resistance test. The test results are shown in fig. 2: the fracturing fluid is used at 160 ℃,170 and 170 s -1 After shearing for 120 min, the viscosity is 77.5 mPas, and meets the requirements (more than or equal to 50 mPas) of the petroleum and natural gas industry standard (SY/T7627-2021). The high-density fracturing fluid system can be used for reservoir reformation at 160 ℃.
Example 13
Comparative experiments on samples of example 1 the comparative polymer was a polyacrylamide copolymer with a molecular weight of 1500 ten thousand and a degree of hydrolysis of 0. The test results are shown in fig. 3: the high-density fracturing fluid constructed by the polymer is at 150 ℃,170 and 170 s -1 After shearing for 120 min, the viscosity is 23.0 mPas does not meet the requirements (more than or equal to 50 mPas) of petroleum and natural gas industry standards (SY/T7627-2021). The high-density fracturing fluid system prepared by the polymer cannot be used for reservoir reformation at 150 ℃. In comparison with the results of example 12, the importance of polymer selection to high density fracturing fluid performance is demonstrated.
Example 14
The samples of example 2 were subjected to a temperature resistance test. The test results are shown in fig. 4: the fracturing fluid is used at 160 ℃,170 and 170 s -1 After shearing for 120 min, the viscosity is 452 mPa.s, and the requirements (more than or equal to 50 mPa.s) of the petroleum and natural gas industry standard (SY/T7627-2021) are met. The high-density fracturing fluid system can be used for reservoir reformation at 160 ℃.
Example 15
The samples of example 3 were subjected to a temperature resistance test. The test results are shown in fig. 5: the fracturing fluid is used at 200 ℃ and 170 s -1 After shearing for 120 min, the viscosity is 692 mPa.s, and the requirement (more than or equal to 50 mPa.s) of the petroleum and natural gas industry standard (SY/T7627-2021) is met. The high-density fracturing fluid system can be used for reservoir reformation at 200 ℃.
Example 16
The base fluid of example 1 was subjected to a resistivity reduction test. The test results are shown in fig. 6: under the conditions of 30 ℃ and 180 (L/min) of flow, the highest resistivity of the high-density fracturing fluid is 65%. The high-density fracturing fluid system has good resistance reducing performance.
Example 17
The base fluid of example 2 was subjected to a resistivity reduction test. The test results are shown in fig. 7: the highest resistivity of the high-density fracturing fluid is 65% under the conditions of 30 ℃ and flow 130 (L/min). The high-density fracturing fluid system has good resistance reducing performance.
Example 18
The base fluid of example 4 was subjected to a resistivity reduction test. The test results are shown in fig. 8: the highest resistivity of the high-density fracturing fluid is 62% under the conditions of 30 ℃ and 120 (L/min) flow. The high-density fracturing fluid system has good resistance reducing performance.
Claims (9)
1. The instant and ultra-high temperature resistant low-friction high-density fracturing fluid is characterized by comprising the following components in parts by weight: 100 parts by mass of weighting salt solution, 1.0-4.0 parts by mass of thickening agent suspension, 0-0.2 parts by mass of pH value regulator, 0.1-1.0 parts by mass of cross-linking agent, 0.01-0.1 parts by mass of high-temperature stabilizer and 0.1-0.5 parts by mass of gel breaker; the density of the weighted salt solution is 1.20-1.50 g/cm 3 Wherein the mass concentration of the salt is 20-70%; the mass content of the polymer in the thickener suspension is 30-40%.
2. The instant ultra-high temperature resistant low friction high density fracturing fluid of claim 1, wherein said weighting salt is one or more of calcium chloride, magnesium chloride, sodium bromide, potassium bromide, sodium nitrate, sodium formate, potassium citrate, sodium citrate, dipotassium hydrogen phosphate, potassium dihydrogen phosphate and potassium pyrophosphate.
3. The instant ultra-high temperature resistant low friction high density fracturing fluid according to claim 1, wherein the thickener suspension is a polymer suspension, the polymer is a partially hydrolyzed polyacrylamide copolymer or polyacrylamide homopolymer, the viscosity average molecular weight of the polymer is 2000-3000 ten thousand, and the degree of hydrolysis is 15-35%.
4. A low friction high density fracturing fluid which is instant and ultra high temperature resistant according to claim 3 wherein said polymer suspension is obtained by dispersing a polymer powder in a dispersion, said dispersion being selected from the group consisting of liquids having a viscosity capable of dispersing and suspending a polymer powder to form a uniform and stable suspension.
5. The quick-dissolving and ultrahigh-temperature-resistant low-friction high-density fracturing fluid according to claim 1, wherein the cross-linking agent is one of an organic zirconium aqueous solution, an organic boron aqueous solution and an organic boron zirconium chelate aqueous solution, and the solid content of the solution is 24-26%.
6. The instant ultra-high temperature resistant low friction high density fracturing fluid according to claim 1, wherein the high temperature stabilizer is polyethylenimine and has a viscosity average molecular weight of 300-10000.
7. The instant ultra-high temperature resistant low friction high density fracturing fluid of claim 1, wherein said pH modifier is one of sodium hydroxide, potassium hydroxide, sodium carbonate and potassium carbonate.
8. The instant ultra-high temperature resistant low friction high density fracturing fluid of claim 1, wherein said breaker is at least one of ammonium persulfate, potassium persulfate, sodium persulfate, and sodium bromate.
9. The method for preparing the instant ultrahigh-temperature-resistant low-friction high-density fracturing fluid according to any one of claims 1 to 8, wherein a polymer suspension is added into a weighted salt solution with a certain proportion, and the mixture is stirred until the polymer is completely dissolved; then adding the cross-linking agent, the pH regulator, the high-temperature stabilizer and the gel breaker, and uniformly stirring.
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