CN117343715A - Efficient emulsification-preventing viscosity reducer, water-based fracturing fluid, and preparation method and application thereof - Google Patents
Efficient emulsification-preventing viscosity reducer, water-based fracturing fluid, and preparation method and application thereof Download PDFInfo
- Publication number
- CN117343715A CN117343715A CN202210740507.5A CN202210740507A CN117343715A CN 117343715 A CN117343715 A CN 117343715A CN 202210740507 A CN202210740507 A CN 202210740507A CN 117343715 A CN117343715 A CN 117343715A
- Authority
- CN
- China
- Prior art keywords
- fracturing fluid
- water
- emulsifying
- viscosity reducer
- sodium
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Pending
Links
- 239000012530 fluid Substances 0.000 title claims abstract description 108
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 72
- 239000003638 chemical reducing agent Substances 0.000 title claims abstract description 50
- 238000002360 preparation method Methods 0.000 title abstract description 14
- -1 polyoxyethylene Polymers 0.000 claims abstract description 40
- 239000000839 emulsion Substances 0.000 claims abstract description 39
- 239000004721 Polyphenylene oxide Substances 0.000 claims abstract description 35
- 229920000570 polyether Polymers 0.000 claims abstract description 35
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 claims abstract description 26
- 239000002562 thickening agent Substances 0.000 claims abstract description 26
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims abstract description 17
- 229920003171 Poly (ethylene oxide) Polymers 0.000 claims abstract description 16
- QQONPFPTGQHPMA-UHFFFAOYSA-N propylene Natural products CC=C QQONPFPTGQHPMA-UHFFFAOYSA-N 0.000 claims abstract description 16
- 125000004805 propylene group Chemical group [H]C([H])([H])C([H])([*:1])C([H])([H])[*:2] 0.000 claims abstract description 16
- KLIIGADLHUOXPS-UHFFFAOYSA-N 2-(1,2,2-triphenylethenyl)phenol Chemical compound OC1=CC=CC=C1C(C=1C=CC=CC=1)=C(C=1C=CC=CC=1)C1=CC=CC=C1 KLIIGADLHUOXPS-UHFFFAOYSA-N 0.000 claims abstract description 14
- 239000002904 solvent Substances 0.000 claims abstract description 9
- LYCAIKOWRPUZTN-UHFFFAOYSA-N Ethylene glycol Chemical compound OCCO LYCAIKOWRPUZTN-UHFFFAOYSA-N 0.000 claims description 35
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 claims description 33
- 239000012752 auxiliary agent Substances 0.000 claims description 17
- 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 16
- 229920002401 polyacrylamide Polymers 0.000 claims description 16
- 239000011734 sodium Substances 0.000 claims description 16
- 229910052708 sodium Inorganic materials 0.000 claims description 16
- 239000003381 stabilizer Substances 0.000 claims description 14
- 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 13
- 239000002455 scale inhibitor Substances 0.000 claims description 13
- CHQMHPLRPQMAMX-UHFFFAOYSA-L sodium persulfate Substances [Na+].[Na+].[O-]S(=O)(=O)OOS([O-])(=O)=O CHQMHPLRPQMAMX-UHFFFAOYSA-L 0.000 claims description 13
- 125000004432 carbon atom Chemical group C* 0.000 claims description 12
- 239000004927 clay Substances 0.000 claims description 12
- 239000000203 mixture Substances 0.000 claims description 11
- 229920000642 polymer Polymers 0.000 claims description 11
- 238000002156 mixing Methods 0.000 claims description 8
- 238000000034 method Methods 0.000 claims description 7
- PEDCQBHIVMGVHV-UHFFFAOYSA-N Glycerine Chemical compound OCC(O)CO PEDCQBHIVMGVHV-UHFFFAOYSA-N 0.000 claims description 6
- KWYUFKZDYYNOTN-UHFFFAOYSA-M Potassium hydroxide Chemical compound [OH-].[K+] KWYUFKZDYYNOTN-UHFFFAOYSA-M 0.000 claims description 6
- 239000003513 alkali Substances 0.000 claims description 6
- 239000003995 emulsifying agent Substances 0.000 claims description 6
- ZBCBWPMODOFKDW-UHFFFAOYSA-N diethanolamine Chemical compound OCCNCCO ZBCBWPMODOFKDW-UHFFFAOYSA-N 0.000 claims description 5
- 150000007529 inorganic bases Chemical class 0.000 claims description 5
- 238000003756 stirring Methods 0.000 claims description 5
- HZAXFHJVJLSVMW-UHFFFAOYSA-N 2-Aminoethan-1-ol Chemical compound NCCO HZAXFHJVJLSVMW-UHFFFAOYSA-N 0.000 claims description 4
- IAYPIBMASNFSPL-UHFFFAOYSA-N Ethylene oxide Chemical compound C1CO1 IAYPIBMASNFSPL-UHFFFAOYSA-N 0.000 claims description 4
- GOOHAUXETOMSMM-UHFFFAOYSA-N Propylene oxide Chemical compound CC1CO1 GOOHAUXETOMSMM-UHFFFAOYSA-N 0.000 claims description 4
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical compound [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 claims description 4
- UIIMBOGNXHQVGW-UHFFFAOYSA-M Sodium bicarbonate Chemical compound [Na+].OC([O-])=O UIIMBOGNXHQVGW-UHFFFAOYSA-M 0.000 claims description 4
- WQDUMFSSJAZKTM-UHFFFAOYSA-N Sodium methoxide Chemical compound [Na+].[O-]C WQDUMFSSJAZKTM-UHFFFAOYSA-N 0.000 claims description 4
- ROOXNKNUYICQNP-UHFFFAOYSA-N ammonium persulfate Chemical compound [NH4+].[NH4+].[O-]S(=O)(=O)OOS([O-])(=O)=O ROOXNKNUYICQNP-UHFFFAOYSA-N 0.000 claims description 4
- 239000000178 monomer Substances 0.000 claims description 4
- 150000007530 organic bases Chemical group 0.000 claims description 4
- 150000003839 salts Chemical class 0.000 claims description 4
- HRPVXLWXLXDGHG-UHFFFAOYSA-N Acrylamide Chemical compound NC(=O)C=C HRPVXLWXLXDGHG-UHFFFAOYSA-N 0.000 claims description 3
- 229920001577 copolymer Polymers 0.000 claims description 3
- 239000002736 nonionic surfactant Substances 0.000 claims description 3
- 239000003002 pH adjusting agent Substances 0.000 claims description 3
- 229920001529 polyepoxysuccinic acid Polymers 0.000 claims description 3
- OWYSSKOUATWAAO-UHFFFAOYSA-N C1(=CC=CC=C1)C=1C(=C(C(=C(C1)O)C=C)C1=CC=CC=C1)C1=CC=CC=C1 Chemical compound C1(=CC=CC=C1)C=1C(=C(C(=C(C1)O)C=C)C1=CC=CC=C1)C1=CC=CC=C1 OWYSSKOUATWAAO-UHFFFAOYSA-N 0.000 claims description 2
- 239000004115 Sodium Silicate Substances 0.000 claims description 2
- GSEJCLTVZPLZKY-UHFFFAOYSA-N Triethanolamine Chemical compound OCCN(CCO)CCO GSEJCLTVZPLZKY-UHFFFAOYSA-N 0.000 claims description 2
- 229910001870 ammonium persulfate Inorganic materials 0.000 claims description 2
- 230000033558 biomineral tissue development Effects 0.000 claims description 2
- 239000006227 byproduct Substances 0.000 claims description 2
- 239000002775 capsule Substances 0.000 claims description 2
- 229910052799 carbon Inorganic materials 0.000 claims description 2
- 238000011065 in-situ storage Methods 0.000 claims description 2
- 239000002480 mineral oil Substances 0.000 claims description 2
- 235000010446 mineral oil Nutrition 0.000 claims description 2
- 230000033116 oxidation-reduction process Effects 0.000 claims description 2
- RPDAUEIUDPHABB-UHFFFAOYSA-N potassium ethoxide Chemical compound [K+].CC[O-] RPDAUEIUDPHABB-UHFFFAOYSA-N 0.000 claims description 2
- USHAGKDGDHPEEY-UHFFFAOYSA-L potassium persulfate Chemical compound [K+].[K+].[O-]S(=O)(=O)OOS([O-])(=O)=O USHAGKDGDHPEEY-UHFFFAOYSA-L 0.000 claims description 2
- 238000005086 pumping Methods 0.000 claims description 2
- 239000004576 sand Substances 0.000 claims description 2
- 229910000030 sodium bicarbonate Inorganic materials 0.000 claims description 2
- 235000017557 sodium bicarbonate Nutrition 0.000 claims description 2
- 229910000029 sodium carbonate Inorganic materials 0.000 claims description 2
- QDRKDTQENPPHOJ-UHFFFAOYSA-N sodium ethoxide Chemical compound [Na+].CC[O-] QDRKDTQENPPHOJ-UHFFFAOYSA-N 0.000 claims description 2
- NTHWMYGWWRZVTN-UHFFFAOYSA-N sodium silicate Chemical compound [Na+].[Na+].[O-][Si]([O-])=O NTHWMYGWWRZVTN-UHFFFAOYSA-N 0.000 claims description 2
- 229910052911 sodium silicate Inorganic materials 0.000 claims description 2
- 239000000725 suspension Substances 0.000 claims description 2
- 239000000080 wetting agent Substances 0.000 claims description 2
- 238000009472 formulation Methods 0.000 claims 2
- 238000004519 manufacturing process Methods 0.000 claims 1
- 239000010779 crude oil Substances 0.000 abstract description 23
- 239000007788 liquid Substances 0.000 abstract description 16
- 230000000694 effects Effects 0.000 abstract description 14
- 230000009467 reduction Effects 0.000 abstract description 10
- 238000004945 emulsification Methods 0.000 abstract description 8
- 238000010276 construction Methods 0.000 abstract description 3
- 239000008398 formation water Substances 0.000 abstract description 3
- 238000002347 injection Methods 0.000 abstract description 3
- 239000007924 injection Substances 0.000 abstract description 3
- 230000002265 prevention Effects 0.000 abstract 1
- 239000003921 oil Substances 0.000 description 32
- 239000008399 tap water Substances 0.000 description 19
- 235000020679 tap water Nutrition 0.000 description 19
- 239000000243 solution Substances 0.000 description 13
- 239000000126 substance Substances 0.000 description 13
- ZMYKITJYWFYRFJ-UHFFFAOYSA-N 4-oxo-4-(2-phenylethylamino)butanoic acid Chemical compound OC(=O)CCC(=O)NCCC1=CC=CC=C1 ZMYKITJYWFYRFJ-UHFFFAOYSA-N 0.000 description 10
- 150000003242 quaternary ammonium salts Chemical class 0.000 description 10
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 9
- 230000000052 comparative effect Effects 0.000 description 9
- 239000004094 surface-active agent Substances 0.000 description 9
- 230000002195 synergetic effect Effects 0.000 description 8
- 238000011161 development Methods 0.000 description 7
- 230000018109 developmental process Effects 0.000 description 7
- 230000008901 benefit Effects 0.000 description 6
- 239000000084 colloidal system Substances 0.000 description 6
- 239000000654 additive Substances 0.000 description 5
- 230000000996 additive effect Effects 0.000 description 5
- 150000001875 compounds Chemical class 0.000 description 5
- 239000011780 sodium chloride Substances 0.000 description 5
- 239000003795 chemical substances by application Substances 0.000 description 4
- 239000001257 hydrogen Substances 0.000 description 4
- 229910052739 hydrogen Inorganic materials 0.000 description 4
- 230000035699 permeability Effects 0.000 description 4
- LPMBTLLQQJBUOO-KTKRTIGZSA-N (z)-n,n-bis(2-hydroxyethyl)octadec-9-enamide Chemical compound CCCCCCCC\C=C/CCCCCCCC(=O)N(CCO)CCO LPMBTLLQQJBUOO-KTKRTIGZSA-N 0.000 description 3
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 3
- AOMUHOFOVNGZAN-UHFFFAOYSA-N N,N-bis(2-hydroxyethyl)dodecanamide Chemical compound CCCCCCCCCCCC(=O)N(CCO)CCO AOMUHOFOVNGZAN-UHFFFAOYSA-N 0.000 description 3
- 230000009471 action Effects 0.000 description 3
- 230000008569 process Effects 0.000 description 3
- 239000003079 shale oil Substances 0.000 description 3
- 208000005156 Dehydration Diseases 0.000 description 2
- 239000003153 chemical reaction reagent Substances 0.000 description 2
- 230000018044 dehydration Effects 0.000 description 2
- 238000006297 dehydration reaction Methods 0.000 description 2
- 230000001804 emulsifying effect Effects 0.000 description 2
- NBVXSUQYWXRMNV-UHFFFAOYSA-N fluoromethane Chemical compound FC NBVXSUQYWXRMNV-UHFFFAOYSA-N 0.000 description 2
- 229910021389 graphene Inorganic materials 0.000 description 2
- 229940031957 lauric acid diethanolamide Drugs 0.000 description 2
- 230000000704 physical effect Effects 0.000 description 2
- 238000012360 testing method Methods 0.000 description 2
- 229920000536 2-Acrylamido-2-methylpropane sulfonic acid Polymers 0.000 description 1
- XHZPRMZZQOIPDS-UHFFFAOYSA-N 2-Methyl-2-[(1-oxo-2-propenyl)amino]-1-propanesulfonic acid Chemical compound OS(=O)(=O)CC(C)(C)NC(=O)C=C XHZPRMZZQOIPDS-UHFFFAOYSA-N 0.000 description 1
- 241001391944 Commicarpus scandens Species 0.000 description 1
- 235000010724 Wisteria floribunda Nutrition 0.000 description 1
- 230000002378 acidificating effect Effects 0.000 description 1
- 125000003118 aryl group Chemical group 0.000 description 1
- 239000010426 asphalt Substances 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 230000015556 catabolic process Effects 0.000 description 1
- 238000013375 chromatographic separation Methods 0.000 description 1
- 239000008139 complexing agent Substances 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 238000006731 degradation reaction Methods 0.000 description 1
- 239000006185 dispersion Substances 0.000 description 1
- 239000003814 drug Substances 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000011156 evaluation Methods 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 239000000295 fuel oil Substances 0.000 description 1
- 239000007789 gas Substances 0.000 description 1
- 238000010438 heat treatment Methods 0.000 description 1
- IPCSVZSSVZVIGE-UHFFFAOYSA-M hexadecanoate Chemical compound CCCCCCCCCCCCCCCC([O-])=O IPCSVZSSVZVIGE-UHFFFAOYSA-M 0.000 description 1
- WGCNASOHLSPBMP-UHFFFAOYSA-N hydroxyacetaldehyde Natural products OCC=O WGCNASOHLSPBMP-UHFFFAOYSA-N 0.000 description 1
- 238000002955 isolation Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- QJGQUHMNIGDVPM-UHFFFAOYSA-N nitrogen group Chemical group [N] QJGQUHMNIGDVPM-UHFFFAOYSA-N 0.000 description 1
- JRKICGRDRMAZLK-UHFFFAOYSA-L peroxydisulfate Chemical compound [O-]S(=O)(=O)OOS([O-])(=O)=O JRKICGRDRMAZLK-UHFFFAOYSA-L 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 230000001737 promoting effect Effects 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 238000001338 self-assembly Methods 0.000 description 1
- MNCGMVDMOKPCSQ-UHFFFAOYSA-M sodium;2-phenylethenesulfonate Chemical compound [Na+].[O-]S(=O)(=O)C=CC1=CC=CC=C1 MNCGMVDMOKPCSQ-UHFFFAOYSA-M 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 238000010998 test method Methods 0.000 description 1
- 238000009736 wetting Methods 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/584—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific surfactants
-
- 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
- C09K8/602—Compositions for stimulating production by acting on the underground formation containing surfactants
- C09K8/604—Polymeric surfactants
-
- 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
-
- 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
- C09K8/86—Compositions based on water or polar solvents containing organic compounds
- C09K8/88—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
Landscapes
- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Colloid Chemistry (AREA)
Abstract
The invention belongs to the technical field of reservoir reconstruction, and particularly relates to a high-efficiency emulsification-prevention viscosity-reduction water-based fracturing fluid system and a preparation method thereof. An anti-emulsifying viscosity reducer comprises the following components: triphenylvinylphenol polyoxyethylene or/and propylene block polyether sulfonate, guerbet alcohol polyoxyethylene or/and propylene block polyether sulfonate, an alkyl alcohol amide compound and a solvent. The anti-emulsifying viscosity reducer can be used for preparing water-based fracturing fluid, and the fracturing fluid comprises the following components: emulsion thickener, anti-emulsifying viscosity reducer, pH regulator, gel breaker and water. The prepared fracturing fluid has good emulsification prevention and viscosity reduction effects, can effectively reduce the occurrence of emulsification of injection fluid and crude oil in fracturing construction, ensures low viscosity of emulsion formed by crude oil, fracturing fluid gel breaking liquid and formation water in a flowback stage, enhances seepage capability, efficiently demulsifies produced fluid and improves the yield of crude oil.
Description
Technical Field
The invention belongs to the technical field of reservoir reconstruction, and particularly relates to a high-efficiency emulsification-prevention viscosity-reduction water-based fracturing fluid system and a preparation method thereof.
Background
The land shale oil reservoir has the characteristics of small distribution range, low maturity, high petroleum density, high wax content and high viscosity, and is a thick oil characteristic. Unlike the development of medium and high permeability heavy oil reservoirs, shale oil reservoirs belong to low or ultra-low permeability reservoirs, and a 'large cluster horizontal well + multi-stage staged' water fracturing process and a low-cost water-based fracturing fluid system are generally adopted. In the actual exploitation process of the tight oil reservoir, the emulsion is seriously emulsified in the reservoir, the viscosity of the emulsion is high, the seepage capability of the emulsion in cracks is greatly reduced, and the demulsification of produced fluid is difficult, so that the yield is seriously reduced. The demulsifier and the viscosity reducer reported at present are mostly applied to the fields related to thick oil chemistry viscosity reduction, emulsion dehydration treatment and gathering and transportation, the thick oil has obvious specificity due to different compositions and physical properties, and the reported medicament has strong demulsification capability or viscosity reduction capability, and the agent have little and high cost, so that the agent and the agent cannot meet the large-scale low-cost benefit development of the thick oil in the prior dense oil reservoir.
Chinese patent CN102746470B discloses a high-efficiency demulsifier for naphthenic thickened oil, which contains modified polyether demulsifier monomers with multi-layer and multi-aromatic ring three-dimensional network structure, but has strong specificity and poor demulsification effect on thickened oil with other different physical properties.
For example, chinese patent CN112409535a discloses a high-dispersibility thick oil viscosity reducer, the molecular structure of which is a monomer copolymer of sodium styrene sulfonate, acrylamide, 2-acrylamido-2-methylpropanesulfonic acid, and the like, and the polymer viscosity reducer is added into a fracturing fluid system, and there is a risk of degradation failure of molecular chains under the action of a high-temperature stratum persulfate gel breaker.
Chinese patent CN 111394080A discloses a formula of an efficient thick oil viscosity reducer, which is a compound system of graphene, alkaline substances and a surfactant or an oil-soluble polymer, and the dosage is large (0.05 mg/ml-0.15 mg/ml) and the cost is too high for a water-based fracturing fluid although the graphene and the alkaline substances act synergistically to reduce the viscosity efficiently.
Therefore, under the development background condition of the shale oil exploitation hydraulic fracturing technology, the development of the efficient emulsification-prevention viscosity-reduction and low-cost water-based fracturing fluid system aiming at the thick oil rich in alkaline condensed ring compounds and high in colloid content (35-40%) has great significance in realizing the development of the oil field benefits. The low-cost and high-efficiency emulsification-prevention viscosity-reduction fracturing fluid system for thick oil or extra thick oil is not reported yet.
The invention aims to provide a low-cost water-based fracturing fluid system with high-efficiency emulsification-prevention viscosity-reduction function for thick oil and a preparation method thereof, so as to solve the technical problems of serious emulsification (high emulsion viscosity and difficult emulsion breaking) and high large-scale development cost of the existing fracturing fluid system and dense reservoir thick oil.
Disclosure of Invention
In order to solve the technical problems, the invention provides a low-cost water-based fracturing fluid system with high-efficiency emulsification-prevention viscosity-reduction function for thick oil, which has the advantages of simple preparation method, better emulsification-prevention viscosity-reduction effect, capability of effectively reducing emulsification of fracturing construction injection fluid and crude oil, low viscosity of emulsion formed by crude oil, fracturing fluid gel breaking liquid and formation water in a flowback stage, enhanced seepage capability, high-efficiency demulsification of produced liquid and improved crude oil yield.
In order to achieve the above object, the technical scheme provided by the invention is as follows:
an anti-emulsifying viscosity reducer comprises the following components: triphenylvinylphenol polyoxyethylene or/and propylene block polyether sulfonate, guerbet alcohol polyoxyethylene or/and propylene block polyether sulfonate, an alkyl alcohol amide compound and a solvent.
Preferably, the solvent is any one or more of water, ethanol, glycol or glycerol;
more preferably, the solvent is a mixture of water and ethylene glycol; mass ratio, water: ethylene glycol=8:2.
Preferably, the molecular structural general formula of the triphenylvinylphenol polyoxyethylene/propylene block polyether sodium sulfonate is shown as formula (I):
the number of ethylene oxide EO in the structure shown in the formula (I) is m=1-30, and the number of propylene oxide PO is n=1-30; more preferably, m=12-18, n=5-10.
The general molecular structural formula of the Guerbet alcohol-based polyoxyethylene/propylene block polyether sodium sulfonate is shown as formula (II):
r in the structure of formula (II) 1 And R is 2 Is long carbon chain alkyl, carbon chain length: r is R 1 The number of carbon atoms of the main chain is 5-20, R 2 The number of carbon atoms of the main chain is 5-20, and the number of ethylene oxide groups: m=1 to 50, number of propylene oxide groups: n=1-50;
more preferably, R 1 The number of carbon atoms of the main chain is 12-18, R 2 The number of main chain carbon atoms is 8-18, m=15-25, n=15-20.
Preferably, the composition of the alkyl alcohol amide compound is 85-90% of long-chain alkyl alcohol amide, 2-5% of alkyl amide ester/alkyl amine ester byproducts, 2-5% of diethanolamine and the balance of water, wherein the molecular structure of the long-chain alkyl alcohol amide is shown as a formula (III):
in the structure shown in the formula (III), R is long carbon chain alkyl, and the number of carbon atoms of a main chain of R is 4-20; more preferably, the number of carbon atoms of the R main chain is 12 to 18.
The invention further aims at providing a preparation method of the anti-emulsifying viscosity reducer, which comprises the following steps:
mixing the triphenyl vinyl phenol polyoxyethylene or/and propylene block polyether sulfonate, the guerbet alcohol polyoxyethylene or/and propylene block polyether sulfonate, the alkyl alcohol amide compound and the solvent.
The invention also aims to provide the application of the anti-emulsifying viscosity reducer in fracturing fluid.
The invention also aims at providing a water-based fracturing fluid, which comprises the following components: emulsion thickener, anti-emulsifying viscosity reducer, pH regulator, gel breaker and water.
Preferably, the mineralization of the water is 0-30000mg/L.
Preferably, the fracturing fluid system comprises, in weight percent: 0.01-1.5% of emulsion thickening agent, 0.1-0.5% of anti-emulsifying viscosity reducer, 0.002-0.3% of pH regulator and 0.01-0.3% of gel breaker.
Preferably, the fracturing fluid system further comprises, in weight percent: 0.2-1.5% of fracturing fluid auxiliary agent;
preferably, the fracturing fluid system further comprises, in weight percent: 0.5-1.2% of auxiliary agent of fracturing fluid.
Preferably, the emulsion thickener comprises, in weight percent: 40-55% of thickening agent, 40-45% of mineral oil, 2-5% of nonionic surfactant type emulsifier, 0.5-1% of suspension stabilizer and 5-10% of low-carbon alcohol nonionic wetting agent.
Preferably, the thickening agent is selected from any one or more of ultrahigh molecular weight polyacrylamide, a copolymer of acrylamide and a temperature-resistant and salt-resistant monomer, a hydrophobically associating polymer and a novel structure polyacrylamide copolymer (comb type, star type, micro-branched type and the like).
More preferably, the thickener is an anti-salt hydrophobically associative polymer.
Preferably, the pH adjuster is an organic base and an inorganic base;
preferably, the organic base comprises any one or more of ethanolamine, diethanolamine, triethanolamine, sodium methoxide, sodium ethoxide and potassium ethoxide;
preferably, the inorganic base comprises any one or more of sodium hydroxide, potassium hydroxide, sodium carbonate, sodium bicarbonate and sodium silicate;
more preferably, the organic base is diethanolamine;
preferably, the inorganic base is sodium hydroxide.
Preferably, the breaker comprises any one or more of ammonium persulfate, potassium persulfate, sodium persulfate, capsule breakers and oxidation-reduction breakers.
More preferably, the breaker selected is sodium persulfate.
Preferably, the fracturing fluid auxiliary agent is selected from any one or more of long-chain alkyl quaternary ammonium salt type clay stabilizer and polyepoxysuccinic acid (sodium) alkaline scale inhibitor.
The purpose of the scale inhibitor adding system is to prevent the fracturing fluid system from breaking gel and scaling in a shaft in a weak alkaline way.
The invention also provides an indoor preparation method of the water-based fracturing fluid, which comprises the following steps:
(1) Adding water, emulsion thickener and pH regulator in certain proportion and stirring;
(2) And meanwhile, adding an anti-emulsifying agent and a fracturing fluid auxiliary agent, and stirring to obtain the anti-emulsifying polymer fracturing fluid system.
Preferably, the pH adjustor is first formulated as a 1-10% solution and then used, preferably a 5% solution.
The invention also provides an on-site preparation method of the water-based fracturing fluid, which comprises the following steps:
and simultaneously pumping water, an emulsion thickener, a pH regulator, an anti-emulsifying agent and a fracturing fluid auxiliary agent into a sand mixing tank according to a proportion, and mixing to obtain the anti-emulsifying polymer fracturing fluid system.
Compared with the prior art, the invention has the technical advantages that:
(1) The anti-emulsifying viscosity reducer is a compound multifunctional additive, and effectively improves the dewatering effect of thick oil, in particular to the demulsification effect of thick oil produced liquid rich in alkaline fused ring compound and high in colloid content (35-40%) through the synergistic effect (hydrogen bond effect, interfacial self-assembly and alkali effect) among the surfactant with a special molecular structure, the small molecular auxiliary agent and the alkaline substance which are easily available in the market.
(2) The anti-emulsifying viscosity-reducing complexing agent provided by the invention has good interfacial activity, and no additional cleanup additive is required to be added in the fracturing fluid system, so that smooth flowback of the fracturing fluid is ensured.
(3) The invention provides a set of high-efficiency emulsification-preventing low-cost water-based fracturing fluid system, which is suitable for thick oil with high colloid content and high basic nitrogen-containing compound content and viscosity of more than 10000 mPa.s, and is technically characterized in that: demulsification effect: demulsification rate (3 min, 80 ℃): not less than 85%, and demulsification rate (24 h,80 ℃): more than or equal to 98 percent; viscosity reduction rate: not less than 80% and other performance indexes meeting the general technical standard of water-based fracturing fluids. The method can effectively reduce the occurrence of emulsification of the injection fluid and the crude oil in the fracturing construction, ensure low viscosity of emulsion formed by the crude oil, the fracturing fluid gel breaking liquid and the formation water in the flowback stage, enhance the seepage capability, efficiently demulsify the produced liquid and improve the yield of the crude oil.
(4) The invention provides a preparation method of an emulsification-prevention viscosity-reduction fracturing fluid system, which is free from mixing, simplifies the on-site fluid preparation process, reduces the comprehensive cost and realizes benefit development.
(5) The surfactant has unique surface-interface activity, wettability, permeability, emulsifying property and other functions, is environment-friendly, has good synergistic effect according to the characteristics of crude oil or thick oil, and can realize rapid demulsification, viscosity reduction, system oil-water interfacial tension reduction and the like in the thick oil exploitation process.
(6) The structure of the gel group in the thickened oil is loose, and the aggregate formed by overlapping and piling up the colloid and the asphaltene lamellar intermolecular hydrogen bond under the polar condition has high viscosity and is not easy to break emulsion. The surfactant can reduce the surface tension and interfacial tension between oil and water and promote the emulsification and dispersion of crude oil, so that the surfactant is widely used in the chemical viscosity reduction exploitation of thick oil. The invention uses the anionic-nonionic surfactant which has the advantages of temperature resistance, salt resistance and no chromatographic separation, and can meet the high temperature resistance requirement and the salt resistance requirement.
The polyether sulfonate with multiple aromatic rings and the polyether sulfonate with double tail chain alcohol blocks have better wettability and permeability, can quickly reach an oil-water interface under the action of a small molecular solvent, can self-assemble or form a thinner three-dimensional network structure through hydrogen bonding and a molecular interface, prevent colloid or asphalt molecules from being connected into a network structure with a stronger structure through the hydrogen bonding, and break up aggregates formed by overlapping and stacking colloid and asphaltene lamellar molecular planes, so that the supermolecular structure in thick oil is converted from a higher level to a lower level, and has more stable oil-water isolation performance and easier demulsification and dehydration.
(7) When the alkali and alkyl alcohol amide compound system is added, the surface tension of the emulsion is lower, which indicates that the alkali and the alkyl alcohol amide compound system have good synergistic effect. From the analysis of the molecular structure of the components of the crude oil, the nitrogen-containing substances in the crude oil are higher, and the acidic or basic condensed-cyclic compounds are mainly used. In general, the addition of alkaline substances has a promoting effect on viscosity reduction of the thickened oil, because the alkaline substances can react with polar components in the crude oil to generate in-situ surfactant substances, so that the surface activity is enhanced. The alkaline substance reacts with the polar component in the thick oil to produce ionized surface active substance, the surface tension is reduced, the alkaline substance accelerates the dispersibility of the ionized surface active substance from the surface to the inside of the solid, so that the polar component is exposed in the alkaline substance, the surface tension is further reduced, and the oil drops are further reduced, thereby achieving the purpose of reducing the viscosity.
Detailed Description
The present invention will be described by way of specific examples, to facilitate understanding and grasping of the technical solution of the present invention, but the present invention is not limited thereto. The experimental methods described in the following examples are all conventional methods unless otherwise specified; the reagents and materials, unless otherwise specified, are commercially available.
The sources of part of reagents in the embodiment of the invention are as follows:
triphenylvinylphenol polyoxyethylene/propylene block polyether sodium sulfonate (TSP, manufactured by southern general Chen wetting chemical Co., ltd.);
guerbet alcohol based polyoxyethylene/propylene block polyether sodium sulfonate (EG, sha Suo (China) chemical Co., ltd.);
alkyl alcohol amide complex (NAS, mitsunobu chemical company, ltd.).
Comparative example:
preparing fracturing fluid by tap water: 0.8 part of emulsion thickening agent (anti-salt polyacrylamide FPY, sichuan photopolymerized chemical Co., ltd.), 1 part of fracturing fluid auxiliary agent (50 wt% of long-chain quaternary ammonium salt organic clay stabilizer GAF-16, sichuan photopolymerized chemical Co., ltd. +20wt% of fluorocarbon cleanup additive OBS, shanghai Futian chemical Co., ltd. +30wt% of polyepoxysuccinate sodium scale inhibitor PESA, hebei collaborative chemical Co., ltd.), 0.1 part of gel breaker (sodium persulfate) and 98.1 parts of tap water. And (3) placing the prepared fracturing fluid system in a water bath kettle at 90 ℃ for breaking gel for 4 hours to obtain a gel breaking solution with thorough gel breaking.
Example 1:
the difference compared to the comparative example is the addition of an alkaline pH adjustor to the fracturing fluid system.
Preparing fracturing fluid by tap water: emulsion thickener (anti-salt polyacrylamide FPY, sichuan photo-polymer chemical Co., ltd.) 0.8 parts, pH regulator 0.2 parts (sodium hydroxide), fracturing fluid auxiliary 1 parts (50 wt% long-chain quaternary ammonium salt organic clay stabilizer GAF-16, sichuan photo-polymer chemical Co., ltd. +20wt% fluorocarbon cleanup agent OBS, shanghai Fuji chemical Co., ltd. +30wt% sodium polyepoxysuccinate scale inhibitor PESA, hebei synergistic chemical Co., ltd.), breaker 0.1 parts (sodium persulfate), tap water 97.9 parts. And (3) placing the prepared fracturing fluid system in a water bath kettle at 90 ℃ for breaking gel for 4 hours to obtain a gel breaking solution with thorough gel breaking.
Example 2:
the difference compared with the comparative example is that the anti-emulsifying viscosity reducer is added into the fracturing liquid system.
Preparing fracturing fluid by tap water: 0.8 part of emulsion thickening agent (anti-salt polyacrylamide FPY, sichuan photopolymerized chemical Co., ltd.), 0.3 part of anti-emulsifying viscosity reducer (30 percent of triphenylvinyl phenol polyether (m=12, n=5) +10 percent of didodecyl polyether sulfonate (m=15, n=20) +15 percent of oleic acid diethanolamide+5 percent of ethylene glycol+50 percent of pure water), 1 part of fracturing fluid additive (50 percent by weight of long-chain quaternary ammonium salt organic clay stabilizer GAF-16, sichuan photopolymerized chemical Co., ltd. +50 percent by weight of polyepoxysuccinate sodium scale inhibitor PESA, hebei synergetic chemical Co., ltd.), 0.1 part of breaker (sodium persulfate) and 97.8 parts of tap water. And (3) placing the prepared fracturing fluid system in a water bath kettle at 90 ℃ for breaking gel for 4 hours to obtain a gel breaking solution with thorough gel breaking.
Example 3:
the difference compared with the comparative example is that an alkaline pH regulator and an anti-emulsifying viscosity reducer are added into the fracturing fluid system.
Preparing fracturing fluid by tap water: 0.8 part of emulsion thickening agent (anti-salt polyacrylamide FPY, sichuan photopolymerized chemical Co., ltd.), 0.15 part of pH regulator (sodium hydroxide), 0.3 part of anti-emulsifying viscosity reducer (30 percent of triphenylvinyl phenol polyether (m=12, n=5) +10 percent of didodecyl polyether sulfonate (m=15, n=20) +15 percent of oleic acid diethanolamide+5 percent of ethylene glycol+40 percent of pure water), 1 part of fracturing fluid auxiliary agent (50 percent of long-chain quaternary ammonium salt organic clay stabilizer GAF-16, sichuan photopolymerized chemical Co., ltd. +50 percent of polyepoxysuccinate sodium scale inhibitor PESA, 0.1 part of breaker (sodium persulfate) and 96.5 parts of tap water. And (3) placing the prepared fracturing fluid system in a water bath kettle at 90 ℃ for breaking gel for 4 hours to obtain a gel breaking solution with thorough gel breaking.
Example 4:
the difference compared to the comparative example is that the fracturing fluid system incorporates an alkaline pH adjuster and a demulsifying viscosity reducer, which differs in composition from example 3.
Preparing fracturing fluid by tap water: 0.8 part of emulsion thickening agent (anti-salt polyacrylamide FPY, sichuan photopolymerized chemical Co., ltd.), 0.15 part of pH regulator (sodium hydroxide), 0.3 part of anti-emulsifying viscosity reducer (40% triphenylvinyl phenol polyether (m=12, n=5) +15% oleic acid diethanolamide+5% ethylene glycol+40% pure water), 1 part of fracturing fluid auxiliary agent (50 wt% long-chain quaternary ammonium salt organic clay stabilizer GAF-16, sichuan photopolymerized chemical Co., ltd. +50wt% polyepoxysuccinate sodium scale inhibitor PESA, hebei synergetic chemical Co., ltd.), 0.1 part of breaker (sodium persulfate) and 96.5 parts of tap water. And (3) placing the prepared fracturing fluid system in a water bath kettle at 90 ℃ for breaking gel for 4 hours to obtain a gel breaking solution with thorough gel breaking.
Example 5:
the difference compared with the comparative example is that the alkaline pH regulator and the anti-emulsifying viscosity reducer are added into the fracturing liquid system, and the composition and the dosage of the anti-emulsifying viscosity reducer are different compared with the example 3.
Preparing fracturing fluid by tap water: 0.8 part of emulsion thickening agent (anti-salt polyacrylamide FPY, sichuan photopolymerized chemical Co., ltd.), 0.15 part of pH regulator (sodium hydroxide), 0.25 part of anti-emulsifying viscosity reducer (40% of triphenylvinyl phenol polyether (m=12, n=5) +15% of didodecyl polyether sulfonate (m=15, n=20) +5% of ethylene glycol+40% of pure water), 1 part of fracturing fluid additive (50 wt% of long-chain quaternary ammonium salt organic clay stabilizer GAF-16, sichuan photopolymerized chemical Co., ltd. +50wt% of polyepoxysuccinate sodium scale inhibitor PESA, hebei collaborative chemical Co., ltd.), 0.1 part of breaker (sodium persulfate) and 97.7 parts of tap water. And (3) placing the prepared fracturing fluid system in a water bath kettle at 90 ℃ for breaking gel for 4 hours to obtain a gel breaking solution with thorough gel breaking.
Example 6:
the difference compared with the comparative example is that the alkaline pH regulator and the anti-emulsifying viscosity reducer are added into the fracturing liquid system, and the composition and the dosage of the anti-emulsifying viscosity reducer are different compared with the example 3.
Preparing fracturing fluid by tap water: 0.8 part of emulsion thickening agent (anti-salt polyacrylamide FPY, sichuan photopolymerized chemical Co., ltd.), 0.15 part of pH regulator (sodium hydroxide), 0.25 part of anti-emulsifying viscosity reducer (35% of triphenylvinyl phenol polyether (m=15, n=8) +5% of ditetradecyl polyether sulfonate (m=18, n=15) +15% of diethanolamide palmitate+5% of ethylene glycol+40% of pure water), 1 part of fracturing fluid auxiliary agent (50 wt% of long-chain quaternary ammonium salt organic clay stabilizer GAF-16, sichuan photopolymerized chemical Co., ltd. +50wt% of sodium polyepoxysuccinate scale inhibitor PESA, hebei's synergistic chemical Co., ltd.), 0.1 part of breaker (sodium persulfate) and 97.7 parts of tap water. And (3) placing the prepared fracturing fluid system in a water bath kettle at 90 ℃ for breaking gel for 4 hours to obtain a gel breaking solution with thorough gel breaking.
Example 7:
the difference compared with the comparative example is that the alkaline pH regulator and the anti-emulsifying viscosity reducer are added into the fracturing liquid system, and the composition and the dosage of the anti-emulsifying viscosity reducer are different compared with the example 3.
Preparing fracturing fluid by tap water: 0.8 part of emulsion thickening agent (anti-salt polyacrylamide FPY, sichuan photopolymerized chemical Co., ltd.), 0.2 part of pH regulator (sodium hydroxide), 0.3 part of anti-emulsifying viscosity reducer (25% of triphenylvinyl phenol polyether (m=18, n=10) +15% of dioctadecyl polyether sulfonate (m=5, n=20) +15% of lauric acid diethanolamide+5% of ethylene glycol+40% of pure water), 1 part of fracturing fluid auxiliary agent (50 wt% of long-chain quaternary ammonium salt organic clay stabilizer GAF-16, sichuan photopolymerized chemical Co., ltd. +50wt% of polyepoxysuccinate scale inhibitor PESA, hebei cooperative chemical Co., ltd.), 0.1 part of breaker (sodium persulfate) and 97.6 parts of tap water. And (3) placing the prepared fracturing fluid system in a water bath kettle at 90 ℃ for breaking gel for 4 hours to obtain a gel breaking solution with thorough gel breaking.
Example 8:
compared with example 7, the water quality of the preparation liquid is different and is 10000mg/L sodium chloride.
10000mg/L sodium chloride is adopted to prepare fracturing fluid: 1 part of emulsion thickening agent (anti-salt polyacrylamide FPY, sichuan photopolymerized chemical Co., ltd.), 0.25 part of pH regulator (sodium hydroxide), 0.35 part of anti-emulsifying viscosity reducer (30 percent of triphenylvinyl phenol polyether (m=18, n=10) +15 percent of didodecyl polyether sulfonate (m=5, n=20) +15 percent of coco diethanolamide+5 percent of ethylene glycol+35 percent of pure water), 1 part of fracturing fluid auxiliary agent (50 percent of long-chain quaternary ammonium salt organic clay stabilizer GAF-16, sichuan photopolymerized chemical Co., ltd. +50 percent of polyepoxysuccinate sodium scale inhibitor PESA, hebei synergetic chemical Co., ltd.), 0.12 part of breaker (sodium persulfate) and 97.8 parts of tap water. And (3) placing the prepared fracturing fluid system in a water bath kettle at 90 ℃ for breaking gel for 4 hours to obtain a gel breaking solution with thorough gel breaking.
Example 9:
compared with example 7, the water quality of the preparation liquid is different and is 30000mg/L sodium chloride.
Preparing fracturing fluid by adopting 30000mg/L sodium chloride: 1.2 parts of emulsion thickening agent (anti-salt polyacrylamide FPY, sichuan photopolymerized chemical Co., ltd.), 0.2 part of pH regulator (sodium hydroxide), 0.3 part of anti-emulsifying viscosity reducer (35% of triphenylvinyl phenol polyether (m=18, n=10) +10% of dioctadecyl polyether sulfonate (m=5, n=20) +20% of lauric acid diethanolamide+5% of ethylene glycol+40% of pure water), 1 part of fracturing fluid auxiliary agent (50 wt% of long-chain quaternary ammonium salt organic clay stabilizer GAF-16, sichuan photopolymerized chemical Co., ltd. +50wt% of polyepoxysuccinate scale inhibitor PESA, 0.12 part of breaker (sodium persulfate) and 97.18 parts of tap water. And (3) placing the prepared fracturing fluid system in a water bath kettle at 90 ℃ for breaking gel for 4 hours to obtain a gel breaking solution with thorough gel breaking.
Effect example:
the invention relates to a preparation method of a blending-free fracturing fluid, which is characterized in that crude oil of a certain block of a Ji-Texal oilfield is used as experimental oil (viscosity 132.4mPa.s at 80 ℃), and the viscosity of an emulsion is tested by referring to an emulsification rate and demulsification rate test method described in a water-based fracturing fluid evaluation method of oil and gas industry standard SY/T5107-2005.
The method comprises the following specific steps:
(1) Testing of demulsification Rate: mixing crude oil and fracturing fluid gel breaking liquid according to the volume ratio of 3:1, placing the mixture into a container, placing the container into a constant-temperature water bath kettle, and heating the mixture to 80 ℃. And (3) placing the constant-temperature mixed liquid into a mixer, regulating a proper rotating speed, stirring for 5min, then pouring the emulsion into a colorimetric tube with a plug scale, and recording the volume of the actual emulsion. Placing the colorimetric tube with the plug graduation filled with the emulsion in an oven at 80 ℃, respectively recording the volumes of the gel breaking liquid separated from 3min, 5min, 10min, 15min, 30min, 60min, 2h, 4h, 10h and 24h, and calculating the demulsification rate.
(2) Testing of viscosity: the viscosity of the crude oil emulsion is tested by using a Brookfield DV-III viscometer (a 0# rotor, 6RPM and at 80 ℃), 4mL of the fracturing fluid system gel breaking liquid is weighed and put into a measuring cup of the viscometer, 12mL of crude oil is weighed and put into the measuring cup, after the crude oil is preheated for 30min, the crude oil emulsion is emulsified and dispersed for 10min by using a handheld emulsifying and dispersing machine, and the viscosity of the emulsion is tested.
Specific experimental results are shown in tables 1 and 2:
TABLE 1 demulsification Performance comparison for different embodiments
As can be seen from the comparison results of the examples in Table 1, neither the comparative example (without the anti-emulsifying viscosity reducer) nor the example 1 (with the alkali, without the anti-emulsifying viscosity reducer) breaks; the demulsification effect of the polyether sulfonate and the alkyl alcohol amide surfactants in the anti-emulsification systems of the example 4 and the example 5 is lower than 80% compared with that of the example 3 and the examples 6-9, and the demulsification rate is lower. From the embodiment 3 and the embodiment 6-the embodiment 9, it can be seen that the alkaline substances and the compound anti-emulsifying viscosity reducer are properly added in the fracturing fluid system, and under the combined action of the alkaline effect, the formation of the anti-emulsifying viscosity reducer and the adjustment of a new oil-water interface, an anti-emulsifying viscosity reducer mixed fracturing fluid system is constructed, and the anti-emulsifying viscosity reducer mixed fracturing fluid system has good demulsification performance (the demulsification rate of 24h reaches 100% and the demulsification rate of 3min is more than 85%) in the tap water to 30000mg/L of saline water, so that the anti-emulsifying function is realized, and the exploitation requirements of oil fields are met.
Table 2 viscosity reduction performance comparison (80 ℃ C., crude oil viscosity: 132.4 mPa.s) for different embodiments
As can be seen from the comparison of the table 2, the crude oil in the comparison example without adding the anti-emulsifying viscosity reducer is emulsified and thickened to about 2.3 times, and the anti-emulsifying viscosity-reducing water-based fracturing fluid system (embodiment 6-embodiment 9) can reduce the viscosity of the crude oil to about 20mPa.s, and the viscosity reduction rate is more than 80%.
The foregoing detailed description is directed to one of the possible embodiments of the present invention, which is not intended to limit the scope of the invention, but is to be accorded the full scope of all such equivalents and modifications so as not to depart from the scope of the invention.
Claims (22)
1. The anti-emulsifying viscosity reducer is characterized by comprising the following components: triphenylvinylphenol polyoxyethylene or/and propylene block polyether sulfonate, guerbet alcohol polyoxyethylene or/and propylene block polyether sulfonate, an alkyl alcohol amide compound and a solvent.
2. The anti-emulsifying viscosity reducer of claim 1 wherein the solvent is any one or more of water, ethanol, ethylene glycol and glycerol.
3. The anti-emulsifying viscosity reducer of claim 1, wherein the molecular structural general formula of the triphenylvinylphenol polyoxyethylene/propylene block polyether sodium sulfonate is shown in formula (I):
wherein in the structure shown in the formula (I), the number of ethylene oxide EO is m=1-30, and the number of propylene oxide PO is n=1-30.
4. A demulsifying viscosity reducer according to claim 3, wherein m = 12-18 and n = 5-10.
5. The anti-emulsifying viscosity reducer of claim 1, wherein the sodium guerbet alcohol-based polyoxyethylene/propylene block polyether sulfonate has a molecular structural formula shown in formula (II):
wherein R in the structure of formula (II) 1 And R is 2 Is long carbon chain alkyl, R 1 The number of carbon atoms of the main chain is 5-20, R 2 The number of carbon atoms of the main chain is 5-20, and the number of ethylene oxide groups: m=1 to 50, number of propylene oxide groups: n=1-50.
6. The anti-emulsifying viscosity breaker of claim 5 wherein R 1 The number of carbon atoms of the main chain is 12-18, R 2 The number of main chain carbon atoms is 8-18, m=15-25, n=15-20.
7. The anti-emulsifying viscosity reducer of claim 1 wherein the alkyl alcohol amide compound comprises 85-90% long chain alkyl alcohol amide, 2-5% alkyl amide ester/alkyl amine ester by-product, 2-5% diethanolamine and the balance water, wherein the long chain alkyl alcohol amide has a molecular structure represented by formula (III):
wherein R in the structure shown in the formula (III) is long carbon chain alkyl, and the number of carbon atoms of a main chain of R is 4-20.
8. The anti-emulsifying viscosity reducer of claim 7 wherein the number of carbon atoms in the R backbone is from 12 to 18.
9. A process for preparing the anti-emulsifying viscosity reducer of any of claims 1-8, comprising the steps of:
mixing the triphenyl vinyl phenol polyoxyethylene or/and propylene block polyether sulfonate, the guerbet alcohol polyoxyethylene or/and propylene block polyether sulfonate, the alkyl alcohol amide compound and the solvent.
10. Use of the anti-emulsifying viscosity reducer according to any of claims 1 to 8 in fracturing fluids.
11. A water-based fracturing fluid comprising the following components: emulsion thickener, the anti-emulsifying viscosity reducer according to any one of claims 1 to 8, a pH regulator, a breaker and water.
12. The water-based fracturing fluid of claim 11, wherein the mineralization of water is 0-30000mg/L.
13. The water-based fracturing fluid of claim 11, wherein the fracturing fluid system comprises, in weight percent: 0.01-1.5% of emulsion thickening agent, 0.1-0.5% of anti-emulsifying viscosity reducer, 0.002-0.3% of pH regulator and 0.01-0.3% of gel breaker.
14. The water-based fracturing fluid of claim 11, wherein said fracturing fluid system further comprises, in weight percent: 0.2-1.5% of fracturing fluid auxiliary agent.
15. The water-based fracturing fluid of claim 11, wherein said fracturing fluid system further comprises, in weight percent: 0.5-1.2% of auxiliary agent of fracturing fluid.
16. The water-based fracturing fluid of claim 11, wherein the emulsion thickener comprises, in weight percent: 40-55% of thickening agent, 40-45% of mineral oil, 2-5% of nonionic surfactant type emulsifier, 0.5-1% of suspension stabilizer and 5-10% of low-carbon alcohol nonionic wetting agent.
17. The water-based fracturing fluid of claim 16, wherein said thickening agent is selected from any one or more of ultra-high molecular weight polyacrylamide, copolymers of acrylamide and temperature-resistant and salt-resistant monomers, hydrophobically associating polymers, comb-structured polyacrylamide copolymers, star-structured polyacrylamide copolymers, and micro-branched structured polyacrylamide copolymers.
18. The water-based fracturing fluid of claim 11, wherein said pH modifier is an organic base and an inorganic base; the organic alkali comprises any one or more of ethanolamine, diethanolamine, triethanolamine, sodium methoxide, sodium ethoxide and potassium ethoxide;
the inorganic base comprises any one or more of sodium hydroxide, potassium hydroxide, sodium carbonate, sodium bicarbonate and sodium silicate.
19. The water-based fracturing fluid of claim 11, wherein said breaker comprises any one or more of ammonium persulfate, potassium persulfate, sodium persulfate, capsule breakers, and oxidation-reduction breakers.
20. The water-based fracturing fluid of claim 14 or 15, wherein the fracturing fluid aid is selected from any one or more of a long-chain alkyl quaternary ammonium salt type clay stabilizer, polyepoxysuccinic acid and a polyepoxysuccinic acid sodium alkali scale inhibitor.
21. A method of indoor formulation of the water-based fracturing fluid of any of claims 11-20, comprising the steps of:
(1) Adding water, emulsion thickener and pH regulator in certain proportion and stirring;
(2) And meanwhile, adding an anti-emulsifying agent and a fracturing fluid auxiliary agent, and stirring to obtain the anti-emulsifying polymer fracturing fluid system.
22. A method of in situ formulation of the water-based fracturing fluid of any of claims 11-20, comprising the steps of:
and simultaneously pumping water, an emulsion thickener, a pH regulator, an anti-emulsifying agent and a fracturing fluid auxiliary agent into a sand mixing tank according to a proportion, and mixing to obtain the anti-emulsifying polymer fracturing fluid system.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202210740507.5A CN117343715A (en) | 2022-06-27 | 2022-06-27 | Efficient emulsification-preventing viscosity reducer, water-based fracturing fluid, and preparation method and application thereof |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202210740507.5A CN117343715A (en) | 2022-06-27 | 2022-06-27 | Efficient emulsification-preventing viscosity reducer, water-based fracturing fluid, and preparation method and application thereof |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN117343715A true CN117343715A (en) | 2024-01-05 |
Family
ID=89369702
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202210740507.5A Pending CN117343715A (en) | 2022-06-27 | 2022-06-27 | Efficient emulsification-preventing viscosity reducer, water-based fracturing fluid, and preparation method and application thereof |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN117343715A (en) |
-
2022
- 2022-06-27 CN CN202210740507.5A patent/CN117343715A/en active Pending
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN102757778B (en) | Fracturing fluid capable of resisting high salinity water quality | |
| CN111826150B (en) | High-temperature-resistant viscosity-reduction oil displacement agent for thick oil steam chemical flooding and preparation method and application thereof | |
| CN109135709B (en) | Viscosity-reducing oil displacement agent and oil displacement system suitable for heavy oil reservoir | |
| CN102952531A (en) | Surfactant for displacing oil of offshore oilfield and preparation method thereof | |
| CN111154475B (en) | Oil displacement agent for reducing interfacial tension of high-wax-content crude oil and preparation method and application thereof | |
| CN110699058A (en) | Osmotic modified viscosity-reducing oil displacement agent for water-flooding thickened oil and preparation method thereof | |
| CN111961457B (en) | Oil displacement complexing agent for heavy oil reservoir and preparation method and application thereof | |
| CN114716992B (en) | Salt-resistant temperature-resistant thick oil emulsifying viscosity reducer and preparation method thereof | |
| CN109111906B (en) | Thick oil emulsifying viscosity reducer | |
| CN112126422B (en) | Drag reducer with high stability and preparation method and application thereof | |
| CN111440604B (en) | Self-demulsification type salt-resistant heavy oil cold recovery oil-displacing agent and preparation method and application thereof | |
| CN102732241B (en) | Easily degradable alkali-free viscosity reducer for thick oil and preparation method thereof | |
| CN102585792B (en) | Low-cost environment-friendly oil-soluble viscosity reducing agent for super heavy oil | |
| CN106833578A (en) | Daiamid Arrcostab is used for the pitch dispersant of High viscosity crude | |
| CN110643341B (en) | Oil-water-mineral interface modifier for heavy oil thermal recovery and preparation method thereof | |
| CN112708408B (en) | Depressurization injection increasing agent for ultra-low permeability oilfield injection well and preparation method and application thereof | |
| CN115960021B (en) | Thickened oil viscosity reducer for improving crude oil recovery ratio and synthesis method thereof | |
| CN117343715A (en) | Efficient emulsification-preventing viscosity reducer, water-based fracturing fluid, and preparation method and application thereof | |
| CN113801338A (en) | Fluid loss reducing composition, fluid loss reducing agent, preparation method and application of fluid loss reducing agent | |
| CN117903080A (en) | Thickened oil viscosity reducer and preparation method thereof | |
| CN101357832B (en) | Comb polymer anti-foaming agent | |
| CN110643340B9 (en) | High-efficiency water-soluble viscosity-reduction oil washing agent for heavy oil thermal recovery and preparation method thereof | |
| CN107418616A (en) | Broad spectrum type ageing oil demulsifier and preparation method thereof | |
| CN115521450B (en) | Polymer and viscosity reducer for thick oil cooling containing same as well as preparation method and application thereof | |
| CN117402603B (en) | Yield-increasing fracturing fluid system with imbibition displacement function |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination |