CN113943567A - Gel breaking method of clean fracturing fluid in hydrocarbon-free environment and application - Google Patents
Gel breaking method of clean fracturing fluid in hydrocarbon-free environment and application Download PDFInfo
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- CN113943567A CN113943567A CN202111222021.4A CN202111222021A CN113943567A CN 113943567 A CN113943567 A CN 113943567A CN 202111222021 A CN202111222021 A CN 202111222021A CN 113943567 A CN113943567 A CN 113943567A
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- 239000012530 fluid Substances 0.000 title claims abstract description 120
- 238000000034 method Methods 0.000 title claims abstract description 15
- VTYYLEPIZMXCLO-UHFFFAOYSA-L Calcium carbonate Chemical compound [Ca+2].[O-]C([O-])=O VTYYLEPIZMXCLO-UHFFFAOYSA-L 0.000 claims abstract description 48
- 239000002994 raw material Substances 0.000 claims abstract description 25
- 229910000019 calcium carbonate Inorganic materials 0.000 claims abstract description 24
- 239000002562 thickening agent Substances 0.000 claims abstract description 24
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 21
- 239000002131 composite material Substances 0.000 claims abstract description 19
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 18
- 239000002738 chelating agent Substances 0.000 claims abstract description 17
- 239000000843 powder Substances 0.000 claims abstract description 15
- 239000003292 glue Substances 0.000 claims abstract description 10
- 239000003208 petroleum Substances 0.000 claims abstract description 10
- -1 alcohol amine Chemical class 0.000 claims abstract description 9
- 239000002280 amphoteric surfactant Substances 0.000 claims abstract description 7
- 239000002455 scale inhibitor Substances 0.000 claims abstract description 7
- KCXVZYZYPLLWCC-UHFFFAOYSA-N EDTA Chemical compound OC(=O)CN(CC(O)=O)CCN(CC(O)=O)CC(O)=O KCXVZYZYPLLWCC-UHFFFAOYSA-N 0.000 claims description 17
- KFZMGEQAYNKOFK-UHFFFAOYSA-N Isopropanol Chemical group CC(C)O KFZMGEQAYNKOFK-UHFFFAOYSA-N 0.000 claims description 16
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims description 11
- 239000002245 particle Substances 0.000 claims description 9
- IXOCGRPBILEGOX-UHFFFAOYSA-N 3-[3-(dodecanoylamino)propyl-dimethylazaniumyl]-2-hydroxypropane-1-sulfonate Chemical compound CCCCCCCCCCCC(=O)NCCC[N+](C)(C)CC(O)CS([O-])(=O)=O IXOCGRPBILEGOX-UHFFFAOYSA-N 0.000 claims description 7
- 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 7
- GSEJCLTVZPLZKY-UHFFFAOYSA-N Triethanolamine Chemical group OCCN(CCO)CCO GSEJCLTVZPLZKY-UHFFFAOYSA-N 0.000 claims description 7
- 229910052708 sodium Inorganic materials 0.000 claims description 7
- 239000011734 sodium Substances 0.000 claims description 7
- DBMJMQXJHONAFJ-UHFFFAOYSA-M Sodium laurylsulphate Chemical compound [Na+].CCCCCCCCCCCCOS([O-])(=O)=O DBMJMQXJHONAFJ-UHFFFAOYSA-M 0.000 claims description 6
- 229940077388 benzenesulfonate Drugs 0.000 claims description 6
- SRSXLGNVWSONIS-UHFFFAOYSA-M benzenesulfonate Chemical compound [O-]S(=O)(=O)C1=CC=CC=C1 SRSXLGNVWSONIS-UHFFFAOYSA-M 0.000 claims description 6
- 235000019333 sodium laurylsulphate Nutrition 0.000 claims description 6
- 239000002904 solvent Substances 0.000 claims description 6
- IYEJVYCOCVJYNV-UHFFFAOYSA-N P1(=O)OC(CO)OP(O1)=O.[Na].[Na] Chemical group P1(=O)OC(CO)OP(O1)=O.[Na].[Na] IYEJVYCOCVJYNV-UHFFFAOYSA-N 0.000 claims description 5
- ZOJBYZNEUISWFT-UHFFFAOYSA-N allyl isothiocyanate Chemical compound C=CCN=C=S ZOJBYZNEUISWFT-UHFFFAOYSA-N 0.000 claims description 3
- MRUAUOIMASANKQ-UHFFFAOYSA-N cocamidopropyl betaine Chemical compound CCCCCCCCCCCC(=O)NCCC[N+](C)(C)CC([O-])=O MRUAUOIMASANKQ-UHFFFAOYSA-N 0.000 claims description 3
- 229940073507 cocamidopropyl betaine Drugs 0.000 claims description 3
- 239000008164 mustard oil Substances 0.000 claims description 3
- KWIUHFFTVRNATP-UHFFFAOYSA-N Betaine Natural products C[N+](C)(C)CC([O-])=O KWIUHFFTVRNATP-UHFFFAOYSA-N 0.000 claims description 2
- MWOBKFYERIDQSZ-UHFFFAOYSA-N benzene;sodium Chemical compound [Na].C1=CC=CC=C1 MWOBKFYERIDQSZ-UHFFFAOYSA-N 0.000 claims description 2
- 229960003237 betaine Drugs 0.000 claims description 2
- 229920001529 polyepoxysuccinic acid Polymers 0.000 claims description 2
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 claims description 2
- 239000003109 Disodium ethylene diamine tetraacetate Substances 0.000 claims 1
- 230000001476 alcoholic effect Effects 0.000 claims 1
- 235000019301 disodium ethylene diamine tetraacetate Nutrition 0.000 claims 1
- 238000001914 filtration Methods 0.000 abstract description 12
- 238000002360 preparation method Methods 0.000 abstract description 6
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical compound [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 abstract description 4
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 abstract description 3
- 238000010276 construction Methods 0.000 abstract description 3
- 230000000694 effects Effects 0.000 abstract description 3
- 239000012065 filter cake Substances 0.000 abstract description 3
- 239000004094 surface-active agent Substances 0.000 abstract description 3
- BHPQYMZQTOCNFJ-UHFFFAOYSA-N Calcium cation Chemical compound [Ca+2] BHPQYMZQTOCNFJ-UHFFFAOYSA-N 0.000 abstract description 2
- 229910001424 calcium ion Inorganic materials 0.000 abstract description 2
- 229910000029 sodium carbonate Inorganic materials 0.000 abstract description 2
- 239000003960 organic solvent Substances 0.000 abstract 1
- 229940077386 sodium benzenesulfonate Drugs 0.000 abstract 1
- MZSDGDXXBZSFTG-UHFFFAOYSA-M sodium;benzenesulfonate Chemical compound [Na+].[O-]S(=O)(=O)C1=CC=CC=C1 MZSDGDXXBZSFTG-UHFFFAOYSA-M 0.000 abstract 1
- 239000007788 liquid Substances 0.000 description 12
- 238000010008 shearing Methods 0.000 description 8
- 239000003921 oil Substances 0.000 description 7
- 239000000463 material Substances 0.000 description 3
- 229910021645 metal ion Inorganic materials 0.000 description 3
- 230000004048 modification Effects 0.000 description 3
- 238000012986 modification Methods 0.000 description 3
- 239000000126 substance Substances 0.000 description 3
- 230000015572 biosynthetic process Effects 0.000 description 2
- 239000010779 crude oil Substances 0.000 description 2
- 230000008569 process Effects 0.000 description 2
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 1
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 102000004190 Enzymes Human genes 0.000 description 1
- 108090000790 Enzymes Proteins 0.000 description 1
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 1
- 239000000853 adhesive Substances 0.000 description 1
- 230000001070 adhesive effect Effects 0.000 description 1
- 150000001298 alcohols Chemical class 0.000 description 1
- ROOXNKNUYICQNP-UHFFFAOYSA-N ammonium peroxydisulfate Substances [NH4+].[NH4+].[O-]S(=O)(=O)OOS([O-])(=O)=O ROOXNKNUYICQNP-UHFFFAOYSA-N 0.000 description 1
- VAZSKTXWXKYQJF-UHFFFAOYSA-N ammonium persulfate Chemical compound [NH4+].[NH4+].[O-]S(=O)OOS([O-])=O VAZSKTXWXKYQJF-UHFFFAOYSA-N 0.000 description 1
- 229910001870 ammonium persulfate Inorganic materials 0.000 description 1
- 230000000903 blocking effect Effects 0.000 description 1
- 239000003715 calcium chelating agent Substances 0.000 description 1
- 229910052799 carbon Inorganic materials 0.000 description 1
- 230000000052 comparative effect Effects 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 238000004132 cross linking Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 150000002978 peroxides Chemical class 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
- 238000011085 pressure filtration Methods 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 239000011780 sodium chloride Substances 0.000 description 1
- 230000000638 stimulation Effects 0.000 description 1
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/66—Compositions based on water or polar solvents
- C09K8/665—Compositions based on water or polar solvents containing inorganic compounds
-
- 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
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/66—Compositions based on water or polar solvents
- C09K8/68—Compositions based on water or polar solvents containing organic compounds
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/84—Compositions based on water or polar solvents
- C09K8/845—Compositions based on water or polar solvents containing inorganic compounds
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- 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
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/26—Gel breakers other than bacteria or enzymes
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Abstract
The invention discloses a gel breaking method of a clean fracturing fluid in a hydrocarbon-free environment and application thereof, and belongs to the technical field of preparation of fracturing fluids for oil fields. The clean fracturing fluid comprises the following raw materials in percentage by mass: 1-6% of thickening agent, 0.2-0.8% of composite breaking and assisting glue agent and the balance of water; wherein the thickening agent comprises an amphoteric surfactant, an organic solvent, alcohol amine, calcium carbonate, a scale inhibitor and the like; the composite breaking and assisting agent comprises petroleum sodium benzene sulfonate and a chelating agent. According to the invention, divalent calcium ions are generated after slow reaction between the filter loss agent sodium carbonate powder and the chelating agent in the fracturing fluid, so that the problems of difficult gel breaking and large filtration loss of surfactant type clean fracturing fluid in a hydrocarbon-free environment are solved, and meanwhile, through the reaction of the chelating agent and the carbonate, a filter cake is effectively removed, the size of a micro-crack is increased, and the fracturing construction effect is improved.
Description
Technical Field
The invention relates to the technical field of preparation of fracturing fluid for oil and gas fields, in particular to a gel breaking method of clean fracturing fluid in a hydrocarbon-free environment and application of the gel breaking method.
Background
Fracturing is one of the main measures for oil and gas stimulation. The VES clean fracturing fluid mainly comprises a surfactant, and has the advantages of simple preparation, low viscosity, high elasticity, no residue, shear resistance, low damage, no need of an internal phase gel breaker and the like, so that the VES clean fracturing fluid is popular with people. Compared with a cross-linking polymer fracturing fluid system, in the fracturing construction process, the VES clean fracturing fluid does not need to be added with gel breakers such as internal phase gel breakers like peroxide or biological enzyme, and can be broken by means of crude oil and stratum saline water in a reservoir, namely the external phase gel breaker, so that the purpose of quick flowback of the fracturing fluid is achieved.
At present, under the conventional and unconventional gas reservoir environments and the environments of stratums without hydrocarbon substances, namely external phase gel breakers, the fracturing fluid stays in a stratum supporting belt and accounts for 60% -80% of the whole fracturing working fluid, and when crude oil or a large amount of stratum water is not met, the fracturing fluid is difficult to completely break gel in a short time. The fracturing fluid which is not broken in the stratum is just like a blocking wall, and a seepage channel between oil gas and the outside is blocked, so that the oil gas yield is not increased and the yield is not reduced after fracturing. In addition, the clean fracturing fluid with low viscosity and high elasticity is greatly lost in the formation cracks in the fracturing process, so that the damage of the fracturing fluid to the formation is increased, the actual using amount of the fracturing fluid is reduced, and the preparation cost of the fracturing fluid is increased.
At present, in order to realize rapid gel breaking of clean fracturing fluid under hydrocarbon-free conditions, substances such as ammonium persulfate as an external phase gel breaker, a surfactant OP-10, alcohols with the carbon number of above 4 and the like are generally added for gel breaking of the fracturing fluid. When the addition amount of the substances is too large, the viscosity of the fracturing fluid is reduced in a short time, the sand carrying and construction effects of the fracturing fluid are seriously influenced, and when the addition amount is small, the fracturing fluid is difficult to realize rapid and thorough gel breaking. The above problems affect the large scale use of clean fracturing fluids in both conventional and unconventional gas reservoirs.
Disclosure of Invention
The invention aims to provide a gel breaking method of a clean fracturing fluid in a hydrocarbon-free environment and application thereof, which aims to solve the problems in the prior art.
To achieve the above object, the present invention provides the following solutions
One of the technical schemes of the invention is as follows: a gel breaking method of clean fracturing fluid in a hydrocarbon-free environment utilizes calcium carbonate and a chelating agent to break gel in the hydrocarbon-free environment.
The calcium carbonate and carbonate reservoirs can react with the chelating agent to increase the concentration of divalent metal ions, so that gel breaking of the fracturing fluid is realized, the size of a core seepage channel of the reservoirs is expanded, oil gas circulation is smooth, and filter cakes are thoroughly eliminated after fracturing is finished; and the calcium carbonate powder can reduce the leakage of the fracturing fluid in the stratum, improve the use efficiency of the fracturing fluid and reduce the preparation cost of the fracturing fluid.
The second technical scheme of the invention is as follows: the clean fracturing fluid comprises the following raw materials in percentage by mass: 1-6% of thickening agent, 0.2-0.8% of composite breaking and assisting glue agent and the balance of water;
the thickening agent comprises an amphoteric surfactant, an alcohol solvent, alcohol amine, calcium carbonate and a scale inhibitor;
the composite breaking aid agent comprises any one of the following combinations:
(1) sodium petroleum benzene sulfonate and chelating agents;
(2) sodium lauryl sulfate and a chelating agent.
Further, the thickening agent comprises the following raw materials in percentage by mass: 40-50% of amphoteric surfactant, 20-30% of alcohol solvent, 5% of alcohol amine, 2-10% of calcium carbonate, 0-5% of scale inhibitor and the balance of water.
Further, the amphoteric surfactant is selected from one of cocamidopropyl hydroxysultaine, cocamidopropyl betaine, mustard oil amidopropyl hydroxysultaine, and cetyl dihydroxyethyl betaine.
Further, the alcohol solvent is selected from isopropanol or ethanol; the scale inhibitor is selected from disodium hydroxyethylidene diphosphonate or polyepoxysuccinic acid; the alcohol amine is triethanolamine.
Further, the calcium carbonate is calcium carbonate powder, and the particle size of the powder is 20-200 mu m.
Further, the composite breaking and assisting glue agent comprises the following raw materials in percentage by mass: the raw materials are as follows: 80-90% of petroleum benzene sodium sulfonate or sodium dodecyl sulfate and 10-20% of chelating agent.
Further, the chelating agent is selected from one of ethylenediamine tetraacetic acid and disodium ethylenediamine tetraacetic acid.
The third technical scheme of the invention is as follows: the application of the clean fracturing fluid in gel breaking in a hydrocarbon-free environment.
The invention discloses the following technical effects:
(1) the method utilizes the reaction of calcium carbonate and a chelating agent to carry out gel breaking of the fracturing fluid, realizes complete gel breaking in a hydrocarbon-free environment, enlarges the application range of a clean fracturing fluid system, and improves the overall level of a large-scale fracturing working fluid technology, so that the clean fracturing fluid is not only suitable for oil reservoir fracturing, but also suitable for gas reservoir fracturing modification.
(2) The calcium carbonate powder in the clean fracturing fluid reacts with the carbonate reservoir and the chelating agent to increase the concentration of divalent metal ions, so that gel breaking of the fracturing fluid is realized, the size of a core seepage passage of the reservoir is expanded, oil gas circulation is smooth, and a filter cake is thoroughly eliminated after fracturing is finished; and the calcium carbonate powder can reduce the leakage of the fracturing fluid in the stratum, improve the use efficiency of the fracturing fluid and reduce the preparation cost of the fracturing fluid.
(3) The invention utilizes the characteristic that the viscosity characteristic of the clean fracturing fluid is sensitive to divalent metal ions (namely, the viscosity of the fracturing fluid is obviously reduced after the divalent salt in the solution exceeds a certain concentration), and CaCO with a certain concentration is added when the fracturing fluid is prepared3The fracturing fluid is prepared from the thickening agent and a chelating agent (EDTA), and gel breaking of the clean fracturing fluid is realized in the hydrocarbon-free environment; sodium carbonate powder in the fracturing fluid is used as a fluid loss agent, so that the fluid loss of the fracturing fluid is reduced; utilizes divalent calcium ions generated by slow reaction of calcium carbonate and chelating agent to realize cleaningThe clean fracturing fluid can be used for thoroughly and rapidly breaking gel in a hydrocarbon-free environment.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings needed in the embodiments will be briefly described below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and it is obvious for those skilled in the art to obtain other drawings without creative efforts.
FIG. 1 is a shear curve of a clean fracturing fluid prepared in example 1 of the present invention;
FIG. 2 is a shear curve of a clean fracturing fluid prepared in example 2 of the present invention;
FIG. 3 is a shear curve of a clean fracturing fluid prepared in example 3 of the present invention;
FIG. 4 is a shear curve of a clean fracturing fluid prepared in example 4 of the present invention;
fig. 5 is a shear curve of the clean fracturing fluid prepared in example 5 of the present invention.
Detailed Description
Reference will now be made in detail to various exemplary embodiments of the invention, the detailed description should not be construed as limiting the invention but as a more detailed description of certain aspects, features and embodiments of the invention.
It is to be understood that the terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting of the invention. Further, for numerical ranges in this disclosure, it is understood that each intervening value, between the upper and lower limit of that range, is also specifically disclosed. Every smaller range between any stated value or intervening value in a stated range and any other stated or intervening value in a stated range is encompassed within the invention. The upper and lower limits of these smaller ranges may independently be included or excluded in the range.
Unless defined otherwise, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this invention belongs. Although only preferred methods and materials are described herein, any methods and materials similar or equivalent to those described herein can be used in the practice or testing of the present invention. All documents mentioned in this specification are incorporated by reference herein for the purpose of disclosing and describing the methods and/or materials associated with the documents. In case of conflict with any incorporated document, the present specification will control.
It will be apparent to those skilled in the art that various modifications and variations can be made in the specific embodiments of the present disclosure without departing from the scope or spirit of the disclosure. Other embodiments will be apparent to those skilled in the art from consideration of the specification. The specification and examples are exemplary only.
As used herein, the terms "comprising," "including," "having," "containing," and the like are open-ended terms that mean including, but not limited to.
Example 1
A clean fracturing fluid:
the thickening agent is composed of the following raw materials in percentage by mass: 45% of cocamidopropyl hydroxysultaine, 25% of isopropanol, 5% of triethanolamine, 5% of calcium carbonate powder (particle size of 30 mu m) and 20% of water.
The composite breaking and assisting glue agent comprises the following raw materials in percentage by mass: 90% sodium petroleum benzenesulfonate and 10% ethylenediaminetetraacetic acid (EDTA).
The clean fracturing fluid consists of the following raw materials in percentage by mass: 2% of thickening agent, 0.25% of composite breaking aid agent and 97.75% of water.
The prepared clean fracturing fluid is 170s at 80 DEG C-1After continuous shearing for 75min, the viscosity of the fracturing fluid is 32mPa.s, the gel breaking viscosity of the fracturing fluid is 5.5mPa.s, the surface tension of the gel breaking liquid is 26.6mN/m, and the filtration loss of 100mL of fracturing fluid is 8.5mL, and the result is shown in figure 1.
Example 2
The thickening agent is composed of the following raw materials in percentage by mass: 45% of mustard oil amidopropyl hydroxysultaine, 25% of isopropanol, 5% of triethanolamine, 10% of calcium carbonate powder (with the particle size of 30 mu m), 5% of disodium hydroxyethylidene diphosphonate (HEDP) and 10% of water.
The composite breaking and assisting glue agent comprises the following raw materials in percentage by mass: 90% sodium petroleum benzenesulfonate and 10% ethylenediaminetetraacetic acid (EDTA).
The clean fracturing fluid consists of the following raw materials in percentage by mass: 1.5 percent of thickening agent, 0.2 percent of compound breaking aid agent and 98.3 percent of water.
The prepared clean fracturing fluid is 170s at 80 DEG C-1After continuous shearing for 75min, the viscosity of the fracturing fluid is 24mPa.s, the gel breaking viscosity of the fracturing fluid is 2.5mPa.s, the surface tension of the gel breaking liquid is 27.2mN/m, and the filtration loss of 100mL of fracturing fluid is 10.5mL, and the result is shown in figure 2.
Example 3
The thickening agent is composed of the following raw materials in percentage by mass: 45% of cocamidopropyl hydroxysultaine, 25% of isopropanol, 5% of triethanolamine, 10% of calcium carbonate powder (particle size of 50 μm), 5% of sodium Polyepoxysuccinate (PESA) and 10% of water.
The composite breaking and assisting glue agent comprises the following raw materials in percentage by mass: 90% sodium petroleum benzenesulfonate and 10% ethylenediaminetetraacetic acid (EDTA).
The clean fracturing fluid consists of the following raw materials in percentage by mass: 2% of thickening agent, 0.25% of composite breaking aid agent and 97.75% of water.
The prepared clean fracturing fluid is 170s at 80 DEG C-1After 80min of continuous shearing, the viscosity of the fracturing fluid is 18mPa.s, the gel breaking viscosity of the fracturing fluid is 1.5mPa.s, the surface tension of the gel breaking liquid is 26.2mN/m, and the filtration loss of 100mL of fracturing fluid is 12.5mL, and the result is shown in figure 3.
Example 4
The thickening agent is composed of the following raw materials in percentage by mass: 45% of cocamidopropyl hydroxysultaine, 25% of isopropanol, 5% of triethanolamine, 10% of calcium carbonate powder (particle size of 50 mu m), 5% of disodium hydroxyethylidene diphosphonate (HEDP) and 10% of water.
The composite breaking and assisting glue agent comprises the following raw materials in percentage by mass: 90% sodium petroleum benzenesulfonate and 10% ethylenediaminetetraacetic acid (EDTA).
The clean fracturing fluid consists of the following raw materials in percentage by mass: 4% of thickening agent, 0.45% of composite breaking aid adhesive and 95.55% of water.
The prepared clean fracturing fluid is 170s at 100 DEG C-1After continuous shearing for 120min, the viscosity of the fracturing fluid is 54mPa.s, the gel breaking viscosity of the fracturing fluid is 3.5mPa.s, the surface tension of the gel breaking liquid is 25.4mN/m, and the filtration loss of 100mL of fracturing fluid is 5.5mL, and the result is shown in FIG. 4.
Example 5
The thickening agent is composed of the following raw materials in percentage by mass: 45% of cocamidopropyl hydroxysultaine, 25% of isopropanol, 5% of triethanolamine, 10% of calcium carbonate powder (particle size of 30 mu m), 5% of disodium hydroxyethylidene diphosphonate (HEDP) and 10% of water.
The composite breaking and assisting glue agent comprises the following raw materials in percentage by mass: 90% sodium lauryl sulfate and 10% ethylenediaminetetraacetic acid (EDTA).
The clean fracturing fluid consists of the following raw materials in percentage by mass: 4% of thickening agent, 0.5% of composite breaking aid gum agent and 95.5% of water.
The prepared clean fracturing fluid is 170s at 100 DEG C-1After 120min of continuous shearing, the viscosity of the fracturing fluid is 42mPa.s, the gel breaking viscosity of the fracturing fluid is 4.0mPa.s, the surface tension of the gel breaking liquid is 26.1mN/m, and the filtration loss of 100mL of the fracturing fluid is 6.5mL, and the result is shown in FIG. 5.
Example 6
The difference of the method is that the clean fracturing fluid consists of the following raw materials in percentage by mass: 6% of thickening agent, 0.8% of composite breaking aid gum agent and 93.2% of water.
The prepared clean fracturing fluid is 170s at 100 DEG C-1After the fracturing fluid is continuously sheared for 80min, the viscosity of the fracturing fluid is 35mPa.s, the gel breaking viscosity of the fracturing fluid is 2.3mPa.s, the surface tension of the gel breaking liquid is 26.2mN/m, and the filtration loss of 100mL of fracturing fluid is 8.1 mL.
Example 7
The difference from example 5 is that the calcium carbonate powder in the thickener had a particle size of 20 μm.
The prepared clean fracturing fluid is 170s at 100 DEG C-1After continuously shearing for 120min, the viscosity is 59mPa.s, the gel breaking viscosity of the fracturing fluid is 3.24mPa.s, and the gel breaking liquid isThe surface tension was 25.8mN/m, and the fluid loss of 100mL of the fracturing fluid was 5.9 mL.
Example 8
The difference from example 5 is that the calcium carbonate powder in the thickener had a particle size of 200. mu.m.
The prepared clean fracturing fluid is 170s at 100 DEG C-1After the fracturing fluid is continuously sheared for 120min, the viscosity of the fracturing fluid is 48mPa.s, the gel breaking viscosity of the fracturing fluid is 3.82mPa.s, the surface tension of the gel breaking liquid is 26.12mN/m, and the filtration loss of 100mL of fracturing fluid is 6.12 mL.
Example 9
The difference from example 5 is that cocamidopropyl hydroxysultaine in the thickener is exchanged for cocamidopropyl betaine.
The prepared clean fracturing fluid is 170s at 100 DEG C-1After the fracturing fluid is continuously sheared for 120min, the viscosity of the fracturing fluid is 38mPa.s, the gel breaking viscosity of the fracturing fluid is 3.22mPa.s, the surface tension of the gel breaking liquid is 26.35mN/m, and the filtration loss of 100mL of fracturing fluid is 8.2 mL.
Example 10
The difference from example 5 is that isopropanol in the thickener was replaced by ethanol.
The prepared clean fracturing fluid is 170s at 100 DEG C-1After the continuous shearing is carried out for 120min, the viscosity is 53.0mPa.s, the gel breaking viscosity of the fracturing fluid is 3.55mPa.s, the surface tension of a gel breaking liquid is 26.25mN/m, and the filtration loss of 100mL of fracturing fluid is 5.8 mL.
Comparative example 1
The difference from example 5 is that the composite breaking and assisting glue agent is composed of the following raw materials in percentage by mass: 99% sodium lauryl sulfate and 1% ethylenediaminetetraacetic acid (EDTA).
The prepared clean fracturing fluid is 170s at 100 DEG C-1After the continuous shearing is carried out for 120min, the viscosity is 41.3mPa.s, the gel breaking viscosity of the fracturing fluid is 3.25mPa.s, the surface tension of a gel breaking liquid is 15.1mN/m, and the filtration loss of 100mL of fracturing fluid is 10.2 mL.
The shear resistance of the fracturing fluid is tested by using a D100/200 high-temperature high-pressure system of an HAAKE MARS60 rheometer. The filtration loss of 100mL fracturing fluid is tested by adopting a high-temperature high-pressure filtration loss instrument produced by Jiangsu Haian petroleum instrument and equipment factories at 25 ℃. The surface tension of the breaker liquid at 25 ℃ was measured by an automatic surface tension meter K100 manufactured by Kluyverson of Germany.
The above-described embodiments are merely illustrative of the preferred embodiments of the present invention, and do not limit the scope of the present invention, and various modifications and improvements of the technical solutions of the present invention can be made by those skilled in the art without departing from the spirit of the present invention, and the technical solutions of the present invention are within the scope of the present invention defined by the claims.
Claims (9)
1. The gel breaking method of the clean fracturing fluid in the hydrocarbon-free environment is characterized in that gel breaking is carried out by using calcium carbonate and a chelating agent in the hydrocarbon-free environment.
2. The clean fracturing fluid is characterized by comprising the following raw materials in percentage by mass: 1-6% of thickening agent, 0.2-0.8% of composite breaking and assisting glue agent and the balance of water;
the thickening agent comprises an amphoteric surfactant, an alcohol solvent, alcohol amine, calcium carbonate and a scale inhibitor;
the composite breaking aid agent comprises any one of the following combinations:
(1) sodium petroleum benzene sulfonate and chelating agents;
(2) sodium lauryl sulfate and a chelating agent.
3. The clean fracturing fluid of claim 1, wherein the thickener is prepared from the following raw materials in percentage by mass: 40-50% of amphoteric surfactant, 20-30% of alcohol solvent, 5% of alcohol amine, 2-10% of calcium carbonate, 0-5% of scale inhibitor and the balance of water.
4. The clean fracturing fluid of claim 1, wherein the amphoteric surfactant is selected from one of cocamidopropyl hydroxysultaine, cocamidopropyl betaine, mustard oil amidopropyl hydroxysultaine, and cetyl dihydroxyethyl betaine.
5. The clean fracturing fluid of claim 1, wherein the alcoholic solvent is selected from isopropanol or ethanol; the scale inhibitor is selected from disodium hydroxyethylidene diphosphonate or polyepoxysuccinic acid; the alcohol amine is triethanolamine.
6. The clean fracturing fluid of claim 1, wherein the calcium carbonate is calcium carbonate powder with a particle size of 20-200 μm.
7. The clean fracturing fluid of claim 1, wherein the composite breaking aid agent comprises the following raw materials in percentage by mass: 80-90% of petroleum benzene sodium sulfonate or sodium dodecyl sulfate and 10-20% of chelating agent.
8. The clean fracturing fluid of claim 1, wherein the chelating agent is selected from one of ethylenediaminetetraacetic acid and disodium ethylenediaminetetraacetate.
9. Use of the clean fracturing fluid of any one of claims 2 to 8 for gel breaking in a hydrocarbon-free environment.
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