CN116042193B - Inverse-emulsion solid-free completion fluid and preparation method and application thereof - Google Patents
Inverse-emulsion solid-free completion fluid and preparation method and application thereof Download PDFInfo
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- CN116042193B CN116042193B CN202111258949.8A CN202111258949A CN116042193B CN 116042193 B CN116042193 B CN 116042193B CN 202111258949 A CN202111258949 A CN 202111258949A CN 116042193 B CN116042193 B CN 116042193B
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- 239000012530 fluid Substances 0.000 title claims abstract description 135
- 239000000839 emulsion Substances 0.000 title claims abstract description 45
- 238000002360 preparation method Methods 0.000 title abstract description 23
- 230000007797 corrosion Effects 0.000 claims abstract description 54
- 238000005260 corrosion Methods 0.000 claims abstract description 54
- 239000003112 inhibitor Substances 0.000 claims abstract description 54
- 239000003995 emulsifying agent Substances 0.000 claims abstract description 42
- 239000002904 solvent Substances 0.000 claims abstract description 42
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 42
- 239000004927 clay Substances 0.000 claims abstract description 41
- 239000003381 stabilizer Substances 0.000 claims abstract description 40
- 230000000844 anti-bacterial effect Effects 0.000 claims abstract description 39
- 239000003899 bactericide agent Substances 0.000 claims abstract description 39
- 239000012267 brine Substances 0.000 claims abstract description 28
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 claims abstract description 28
- 238000000034 method Methods 0.000 claims abstract description 10
- -1 alkyl phenolic resin Chemical compound 0.000 claims description 48
- 239000000203 mixture Substances 0.000 claims description 31
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical compound [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 claims description 24
- 229920000056 polyoxyethylene ether Polymers 0.000 claims description 20
- 229940051841 polyoxyethylene ether Drugs 0.000 claims description 20
- 229920001451 polypropylene glycol Polymers 0.000 claims description 20
- KFZMGEQAYNKOFK-UHFFFAOYSA-N Isopropanol Chemical compound CC(C)O KFZMGEQAYNKOFK-UHFFFAOYSA-N 0.000 claims description 18
- SXRSQZLOMIGNAQ-UHFFFAOYSA-N Glutaraldehyde Chemical group O=CCCCC=O SXRSQZLOMIGNAQ-UHFFFAOYSA-N 0.000 claims description 17
- 150000001412 amines Chemical group 0.000 claims description 17
- 229920000768 polyamine Polymers 0.000 claims description 15
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims description 13
- OAYXUHPQHDHDDZ-UHFFFAOYSA-N 2-(2-butoxyethoxy)ethanol Chemical compound CCCCOCCOCCO OAYXUHPQHDHDDZ-UHFFFAOYSA-N 0.000 claims description 12
- 239000004280 Sodium formate Substances 0.000 claims description 12
- 239000007864 aqueous solution Substances 0.000 claims description 12
- 239000001103 potassium chloride Substances 0.000 claims description 12
- 235000011164 potassium chloride Nutrition 0.000 claims description 12
- HLBBKKJFGFRGMU-UHFFFAOYSA-M sodium formate Chemical compound [Na+].[O-]C=O HLBBKKJFGFRGMU-UHFFFAOYSA-M 0.000 claims description 12
- 235000019254 sodium formate Nutrition 0.000 claims description 12
- MTNDZQHUAFNZQY-UHFFFAOYSA-N imidazoline Chemical compound C1CN=CN1 MTNDZQHUAFNZQY-UHFFFAOYSA-N 0.000 claims description 11
- 239000004698 Polyethylene Substances 0.000 claims description 10
- 239000005011 phenolic resin Substances 0.000 claims description 10
- 229920001568 phenolic resin Polymers 0.000 claims description 10
- 229920000573 polyethylene Polymers 0.000 claims description 10
- 150000003839 salts Chemical class 0.000 claims description 7
- 150000001875 compounds Chemical class 0.000 claims description 5
- QJEBJKXTNSYBGE-UHFFFAOYSA-N 2-(2-heptadecyl-4,5-dihydroimidazol-1-yl)ethanol Chemical compound CCCCCCCCCCCCCCCCCC1=NCCN1CCO QJEBJKXTNSYBGE-UHFFFAOYSA-N 0.000 claims description 3
- 125000005262 alkoxyamine group Chemical group 0.000 claims description 3
- GQOKIYDTHHZSCJ-UHFFFAOYSA-M dimethyl-bis(prop-2-enyl)azanium;chloride Chemical compound [Cl-].C=CC[N+](C)(C)CC=C GQOKIYDTHHZSCJ-UHFFFAOYSA-M 0.000 claims description 3
- JRBPAEWTRLWTQC-UHFFFAOYSA-N dodecylamine Chemical compound CCCCCCCCCCCCN JRBPAEWTRLWTQC-UHFFFAOYSA-N 0.000 claims description 3
- WXMKPNITSTVMEF-UHFFFAOYSA-M sodium benzoate Chemical compound [Na+].[O-]C(=O)C1=CC=CC=C1 WXMKPNITSTVMEF-UHFFFAOYSA-M 0.000 claims description 3
- 235000010234 sodium benzoate Nutrition 0.000 claims description 3
- 239000004299 sodium benzoate Substances 0.000 claims description 3
- 235000015393 sodium molybdate Nutrition 0.000 claims description 3
- 239000011684 sodium molybdate Substances 0.000 claims description 3
- TVXXNOYZHKPKGW-UHFFFAOYSA-N sodium molybdate (anhydrous) Chemical compound [Na+].[Na+].[O-][Mo]([O-])(=O)=O TVXXNOYZHKPKGW-UHFFFAOYSA-N 0.000 claims description 3
- 238000003756 stirring Methods 0.000 claims description 3
- RZLVQBNCHSJZPX-UHFFFAOYSA-L zinc sulfate heptahydrate Chemical compound O.O.O.O.O.O.O.[Zn+2].[O-]S([O-])(=O)=O RZLVQBNCHSJZPX-UHFFFAOYSA-L 0.000 claims description 3
- 239000007787 solid Substances 0.000 claims 1
- 239000010779 crude oil Substances 0.000 abstract description 76
- 238000010276 construction Methods 0.000 abstract description 22
- 238000004945 emulsification Methods 0.000 abstract description 19
- 238000000926 separation method Methods 0.000 abstract description 17
- 230000006378 damage Effects 0.000 abstract description 10
- 230000000694 effects Effects 0.000 abstract description 9
- 239000003129 oil well Substances 0.000 abstract description 6
- 230000008719 thickening Effects 0.000 abstract description 6
- 230000008569 process Effects 0.000 abstract description 5
- 238000005086 pumping Methods 0.000 abstract description 4
- 239000007790 solid phase Substances 0.000 abstract description 4
- 239000000126 substance Substances 0.000 abstract description 3
- 239000003921 oil Substances 0.000 description 32
- 239000000243 solution Substances 0.000 description 32
- 238000009472 formulation Methods 0.000 description 14
- 241000554155 Andes Species 0.000 description 13
- 238000012360 testing method Methods 0.000 description 13
- 239000012224 working solution Substances 0.000 description 13
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 8
- 238000010586 diagram Methods 0.000 description 7
- 238000011161 development Methods 0.000 description 6
- 230000018109 developmental process Effects 0.000 description 6
- 125000002636 imidazolinyl group Chemical group 0.000 description 6
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- 238000004519 manufacturing process Methods 0.000 description 5
- 238000011282 treatment Methods 0.000 description 5
- HUMNYLRZRPPJDN-UHFFFAOYSA-N benzaldehyde Chemical compound O=CC1=CC=CC=C1 HUMNYLRZRPPJDN-UHFFFAOYSA-N 0.000 description 4
- 230000018044 dehydration Effects 0.000 description 4
- 238000006297 dehydration reaction Methods 0.000 description 4
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- 239000003795 chemical substances by application Substances 0.000 description 3
- 238000013461 design Methods 0.000 description 3
- 150000002462 imidazolines Chemical group 0.000 description 3
- LVSCGHXBWWOJLY-UHFFFAOYSA-N 1-chloropropane;n-methylmethanamine Chemical compound CNC.CCCCl LVSCGHXBWWOJLY-UHFFFAOYSA-N 0.000 description 2
- 239000008186 active pharmaceutical agent Substances 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 238000011156 evaluation Methods 0.000 description 2
- 239000007789 gas Substances 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 239000002736 nonionic surfactant Substances 0.000 description 2
- QNGNSVIICDLXHT-UHFFFAOYSA-N para-ethylbenzaldehyde Natural products CCC1=CC=C(C=O)C=C1 QNGNSVIICDLXHT-UHFFFAOYSA-N 0.000 description 2
- 238000011056 performance test Methods 0.000 description 2
- 230000009467 reduction Effects 0.000 description 2
- 239000004576 sand Substances 0.000 description 2
- 150000003384 small molecules Chemical class 0.000 description 2
- 238000005063 solubilization Methods 0.000 description 2
- 230000007928 solubilization Effects 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- BDAGIHXWWSANSR-UHFFFAOYSA-M Formate Chemical compound [O-]C=O BDAGIHXWWSANSR-UHFFFAOYSA-M 0.000 description 1
- 241001460678 Napo <wasp> Species 0.000 description 1
- 208000027418 Wounds and injury Diseases 0.000 description 1
- 230000032683 aging Effects 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000033558 biomineral tissue development Effects 0.000 description 1
- 238000009933 burial Methods 0.000 description 1
- 150000001768 cations Chemical class 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 239000006185 dispersion Substances 0.000 description 1
- 230000001804 emulsifying effect Effects 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
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- 208000014674 injury Diseases 0.000 description 1
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- 238000012423 maintenance Methods 0.000 description 1
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- 230000007246 mechanism Effects 0.000 description 1
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- 229920000620 organic polymer Polymers 0.000 description 1
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- 230000000704 physical effect Effects 0.000 description 1
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- 239000002994 raw material Substances 0.000 description 1
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Classifications
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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
- C09K8/02—Well-drilling compositions
- C09K8/04—Aqueous well-drilling compositions
- C09K8/06—Clay-free compositions
-
- 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
-
- 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
- C09K2208/12—Swell inhibition, i.e. using additives to drilling or well treatment fluids for inhibiting clay or shale swelling or disintegrating
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- 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)
- Agricultural Chemicals And Associated Chemicals (AREA)
Abstract
The invention provides an inverse-emulsion solid-free completion fluid, a preparation method and application thereof, wherein the inverse-emulsion solid-free completion fluid comprises monovalent brine, 0.05 to 0.5 percent of mutual solvent, 0.05 to 1.0 percent of inverse emulsifier, 0.5 to 2.0 percent of clay stabilizer, 0 to 0.5 percent of corrosion inhibitor and 0 to 0.5 percent of bactericide by volume of the monovalent brine. After the reverse-emulsified solid-free completion fluid is contacted and mixed with crude oil in a stratum, the reverse-emulsified solid-free completion fluid can be unfolded on an oil-water interface, film forming substances in the crude oil are replaced, the film strength is reduced, emulsion is damaged, oil-water separation is maintained, the reverse emulsification effect of the completion fluid is realized, the contact of a shaft working fluid and the crude oil in the well completion operation of a reservoir is prevented, and the thickening of the shaft fluid, the increase of viscosity, the difficulty in pumping, the blockage of an oil well and the damage of emulsion and solid phase to a high-pore-permeability stratum caused by the emulsion are avoided. Therefore, the reverse-emulsified solid-free completion fluid has the advantages of good rheological property, small circulating friction resistance and pressure loss in the construction process, simple field preparation, low cost and the like.
Description
Technical Field
The invention belongs to the technical field of well completion fluid formulas and treatment processes, and particularly relates to an inverse-emulsion solid-free well completion fluid, a preparation method and application thereof.
Background
The well completion fluid is working fluid for well completion operation of the oil and gas well, and is not required to cause damage to a production layer, and is beneficial to later construction operation. The oil resources in the northwest of the south america of the early-end places of the ecuador are quite rich, the service workload of the well completion technology rises year by year, the construction stratum conditions are greatly different, and the well completion working fluid is required to solve the complex problems in the well completion construction process and reduce the subsequent operation cost.
The main oil layer of the eastern oil field of the ecuador is NAPO groups of M1 sand layers and T, U sand layers, and the secondary oil layers are HOLLIN groups of chalk system and the BT groups of sandstone of chalk-ancient oil field, and the burial depth is from 6600 feet to 10000 feet. The oil layer belongs to a medium-high porosity (12% -25%), high permeability (400-4000 md) reservoir, the stratum pressure coefficient is 1.03-1.07, the temperature is 90-95 ℃, and the physical properties of the reservoir are good. The horizontal well of the oil well is completed by using an open hole screen pipe, the directional well is a sleeve perforation well completion, during the well completion operation, the well completion fluid is mixed with the crude oil of the stratum, the treating agent in the well completion fluid causes the interfacial tension of oil and water to change, emulsification occurs, the stratum fluid is thickened, the production pump is caused to be high, the pumping is difficult, sometimes even a pipeline is blocked, and the subsequent operation difficulty is increased. Meanwhile, because the hydraulic column pressure difference of the completion fluid is higher than the idle pressure of the oil layer, the completion fluid inevitably enters the pores of the oil layer and contacts with crude oil in the pores of the oil layer to form emulsion, and the emulsion with the size larger than that of pore throats can block the pores, increase viscosity, reduce the effective flow of hydrocarbon and damage the productivity of the reservoir. Emulsification of completion fluids and formation crude oil is one of the major problems faced by oil wells in the oil field such as ecuador.
Conventional completion fluids typically contain solid phases and clays, which can be very damaging to the reservoir. In order to reduce reservoir damage, solids-free completion fluids are of general interest. The solid-phase-free completion fluid mainly uses soluble salt as a weighting agent, has wide density adjustable range, has the advantages of temperature resistance, salt resistance and the like, and meets the harsh reservoir protection requirements due to no particulate matters and clay. The existing solid-free completion fluid generally takes water as a continuous phase, and can be divided into: clean brine completion fluids, formate completion fluids, organic polymer completion fluids, weak gel completion fluids, and the like. Although a series of solid-free completion fluids have been developed, there are a number of disadvantages in the plugging and collapse and leakage preventing capabilities, prevention of emulsification of crude oil, reduction of treatment costs, etc. of existing completion fluids for high temperature, high pressure, high mineralization deep wells and ultra deep wells.
Disclosure of Invention
In order to solve the problems and the defects existing in the prior art, the invention provides an inverse emulsion solid-free completion fluid technology based on the indoor oilfield chemistry research by utilizing the existing equipment and a completion fluid treatment method, and is particularly suitable for the completion construction of directional wells and horizontal wells of high-permeability and high-yield reservoirs similar to the Gao-duo Oriente basin.
The invention also provides a preparation method and application of the inverse emulsion solid-free completion fluid, which solve the problems of formation damage caused by mixed fluid thickening and emulsification due to emulsification of the completion fluid in contact with crude oil, meet the requirements of well completion operation in ecuador and other areas, reduce non-production aging, reduce reservoir damage, lower subsequent cost and improve well completion construction efficiency.
In order to achieve the above purpose, the technical scheme adopted by the invention is as follows:
an inverse-emulsified solid-free completion fluid comprises monovalent brine, 0.05-0.5% of mutual solvent, 0.05-1.0% of inverse emulsifier, 0.5-2.0% of clay stabilizer, 0-0.5% of corrosion inhibitor and 0-0.5% of bactericide by volume of the monovalent brine.
Further, the mass concentration of the monovalent brine is 1.0-30%.
Further, the monovalent brine is one or a mixture of potassium chloride aqueous solution and sodium formate aqueous solution.
Further, the mutual solvent is one or a mixture of more of isopropanol, ethanol and diethylene glycol butyl ether.
Further, the inverse emulsifier is any one of an AR type nonionic surfactant and an AE type nonionic surfactant, and specifically is alkyl phenolic resin polyoxypropylene polyoxyethylene ether AR101, AR102, AR103 and the like; polyethylene polyamine polyoxypropylene polyoxyethylene ether AE401, AE402, AE405 and the like.
Further, the clay stabilizer is a cationic quaternary ammonium salt.
Specifically, the cationic quaternary ammonium salt is preferably one of dimethyl diallyl ammonium chloride, polyepichlorohydrin-dimethylamine (PTA) and small molecule polyamine (cocoamidomethyl) MEA.
Further, the corrosion inhibitor is an amine corrosion inhibitor and an imidazoline corrosion inhibitor. The amine corrosion inhibitor is preferably organic amine CA101, dodecyl amine, long-chain quaternary amine, alkoxyamine and the like, the imidazoline corrosion inhibitor is preferably imidazoline or derivatives thereof, and can also be a compound imidazoline corrosion inhibitor disclosed in published patent CN201310380304.0, wherein the composition and mass concentration of the compound imidazoline corrosion inhibitor are 20-30 percent of heptadecyl hydroxyethyl imidazoline, 10-20 percent of sodium benzoate, 5-10 percent of zinc sulfate heptahydrate, 5-10 percent of sodium molybdate and 30-60 percent of water, and the commodity code is G707-KLH.
Further, the bactericide is a nonionic bactericide, specifically glutaraldehyde, benzaldehyde and the like, preferably glutaraldehyde.
A preparation method of an inverse emulsion solid-free completion fluid comprises the following steps:
S1, preparing monovalent salt water: mixing one or two of potassium chloride and sodium formate with clear water, and stirring until the mixture is completely dissolved to prepare monovalent salt water with the mass concentration of 1-30%;
S2, adding 0.05-0.5% of mutual solvent, 0.05-1.0% of inverse emulsifier, 0.5-2.0% of clay stabilizer, 0-0.5% of corrosion inhibitor and 0-0.5% of bactericide into the monovalent brine prepared in the step S1 at normal temperature and normal pressure, and uniformly mixing to obtain the completion working fluid.
The application of the reverse-emulsified solid-free completion fluid can be used for casing completion, open hole or screen well completion; when the well completion fluid is used for casing well completion, the well completion fluid comprises monovalent brine, 0.1 to 0.5 percent of mutual solvent, 0.1 to 1.0 percent of inverse emulsifier, 1.0 to 2.0 percent of clay stabilizer, 0 to 0.5 percent of corrosion inhibitor and 0 to 0.5 percent of bactericide according to the volume of the monovalent brine; when the well completion fluid is used for open hole or screen pipe well completion, the well completion fluid comprises 0.1-0.5% of a mutual solvent, 0.1-1.0% of an inverse emulsifier and 1.0-2.0% of a clay stabilizer by the volume of monovalent brine.
By adopting the technical scheme, the invention has the following advantages:
1. The invention is based on preventing emulsification and thickening, emulsion from damaging stratum, and according to the fluid property of oil reservoir, combining treatments such as inverse emulsifier, mutual solvent, etc., to form inverse emulsification solid-free completion fluid with phase change and solubilization, when the inverse emulsification solid-free completion fluid contacts with crude oil of stratum, it can be unfolded on the oil-water interface, displacing film forming matter in crude oil, reducing film strength to break emulsion, maintaining oil-water separation, realizing inverse emulsification of completion fluid, preventing wellbore working fluid from emulsifying with crude oil in reservoir completion operation, avoiding wellbore fluid thickening, viscosity rise, pumping difficulty, oil well blockage, and damage of emulsion, solid phase to high pore-permeability stratum.
2. The completion fluid provided by the invention has good rheological property and small cycle friction and pressure loss in the construction process; the well completion operation requirements of the directional well and the horizontal well of the ecuador and other high-porosity high-yield reservoirs are met, the non-production time is reduced, the reservoir injury is reduced, the operation risk and the production cost are reduced, and the well completion operation efficiency is effectively improved.
3. The raw materials used for preparing the inverse emulsion solid-free completion fluid can be purchased in the market, and have the advantages of wide and sufficient sources, low cost, simple field preparation, easy operation and maintenance and convenient implementation.
The foregoing description is only an overview of the technical solution of the present invention, and in order to make the technical means of the present invention more clearly understood, it can be implemented according to the content of the specification, and the following detailed description of the preferred embodiments of the present invention will be given with reference to the accompanying drawings.
Drawings
In order to more clearly illustrate the technical solutions of the embodiments of the present invention, the drawings that are 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 other designs and drawings can be obtained according to these drawings without inventive effort for a person skilled in the art.
FIG. 1 is a diagram of an observation standard for compatibility evaluation after mixing an inverse emulsion solid-free completion fluid with crude oil;
FIG. 2 is an observation diagram of the mixing and separating effects of the completion working fluid and crude oil in different proportions in example 1;
FIG. 3 is an observation diagram of the effect of mixing and separating the completion fluid and crude oil according to the embodiment 2 in different proportions;
FIG. 4 is an observation diagram of the effect of mixing and separating the completion fluid and crude oil according to the embodiment 3 in different proportions;
FIG. 5 is an observation diagram of the effect of mixing and separating the completion fluid and crude oil according to the embodiment 4 in different proportions;
FIG. 6 is an observation diagram of the effect of mixing and separating the completion fluid and crude oil according to the embodiment 5 in different proportions;
FIG. 7 is an observation diagram of the effect of mixing and separating the completion fluid and crude oil according to the embodiment 6 in different proportions;
FIG. 8 is a graph of time and degree of separation observations of the completion fluid from crude oil of example 7;
FIG. 9 is a graph of observations of time and degree of separation of the completion fluid from crude oil of example 8;
FIG. 10 is a graph of observations of time and degree of separation of completion fluid from crude oil of example 9;
FIG. 11 is a graph of time and degree of separation observations of the completion fluid from crude oil of example 10;
FIG. 12 is a graph of observations of time and degree of separation of completion fluid from crude oil of example 11;
FIG. 13 is a graph of observations of time and degree of separation of the completion fluid from crude oil of example 12.
Detailed Description
Further advantages and effects of the present invention will become apparent to those skilled in the art from the disclosure of the present specification, by describing the embodiments of the present invention with specific examples.
It should be noted that the implementation conditions used in the examples may be further adjusted according to the specific experimental environment, and the implementation conditions that are not noted are generally conditions in the conventional experiments. The preparation methods mentioned in the invention are all conventional methods unless otherwise specified; all the starting materials mentioned in the examples below were obtained from the commercial sources disclosed, unless otherwise specified.
The invention provides an inverse-emulsified solid-free completion fluid, which comprises monovalent brine, 0.05 to 0.5 percent of mutual solvent, 0.05 to 1.0 percent of inverse emulsifier, 0.5 to 2.0 percent of clay stabilizer, 0 to 0.5 percent of corrosion inhibitor and 0 to 0.5 percent of bactericide by volume of the monovalent brine.
Further, the mass concentration of the monovalent brine is 1.0-30%.
Further, the monovalent brine is one or a mixture of potassium chloride aqueous solution and sodium formate aqueous solution.
Further, the mutual solvent is one or a mixture of more of isopropanol, ethanol and diethylene glycol butyl ether.
Further, the inverse emulsifier is any one of alkyl phenolic resin polyoxypropylene polyoxyethylene ether and polyethylene polyamine polyoxypropylene polyoxyethylene ether. The alkyl phenolic resin polyoxypropylene polyoxyethylene ether is preferably AR series, such as AR101, AR102, AR103 and the like; the polyethylene polyamine polyoxypropylene polyoxyethylene ether is preferably AE series, such as AE401, AE402, AE405, etc.
Further, the clay stabilizer is a cationic quaternary ammonium salt. Specifically, the cationic quaternary ammonium salt is preferably one of dimethyl diallyl ammonium chloride, polyepichlorohydrin-dimethylamine (PTA) and small molecule polyamine (cocoamidomethyl) MEA.
Further, the corrosion inhibitor is an amine corrosion inhibitor and an imidazoline corrosion inhibitor. The amine corrosion inhibitor is preferably organic amine CA101, dodecyl amine, long-chain quaternary amine, alkoxyamine and the like, the imidazoline corrosion inhibitor is preferably imidazoline or derivatives thereof, and can also be a compound imidazoline corrosion inhibitor disclosed in published patent CN201310380304.0, wherein the composition and mass concentration of the compound imidazoline corrosion inhibitor are 20-30 percent of heptadecyl hydroxyethyl imidazoline, 10-20 percent of sodium benzoate, 5-10 percent of zinc sulfate heptahydrate, 5-10 percent of sodium molybdate and 30-60 percent of water, and the commodity code is G707-KLH.
Further, the bactericide is a nonionic bactericide, specifically glutaraldehyde, benzaldehyde and the like, preferably glutaraldehyde.
The invention also provides a preparation method of the inverse-emulsion solid-free completion fluid, which comprises the following steps: s1, preparing a brine solution base solution (monovalent brine): mixing one or two of potassium chloride and sodium formate with clear water, and stirring until the mixture is completely dissolved to prepare a saline solution base solution with the mass concentration of 1-30%;
S2, adding 0.05-0.5% of mutual solvent, 0.05-1.0% of inverse emulsifier, 0.5-2.0% of clay stabilizer, 0-0.5% of corrosion inhibitor and 0-0.5% of bactericide into the saline solution base solution prepared in the step S1 at normal temperature and normal pressure, and uniformly mixing to obtain the completion working solution.
The invention also provides application of the inverse emulsion solid-free completion fluid, which can be used for casing completion, open hole completion or screen pipe completion; when the well completion fluid is used for casing well completion, the well completion fluid comprises monovalent brine, 0.1 to 0.5 percent of mutual solvent, 0.1 to 1.0 percent of inverse emulsifier, 1.0 to 2.0 percent of clay stabilizer, 0 to 0.5 percent of corrosion inhibitor and 0 to 0.5 percent of bactericide according to the volume of the monovalent brine; when the well completion fluid is used for open hole or screen pipe well completion, the well completion fluid comprises 0.1-0.5% of a mutual solvent, 0.1-1.0% of an inverse emulsifier and 1.0-2.0% of a clay stabilizer by the volume of monovalent brine.
The reaction mechanism of the invention is as follows:
the invention is based on preventing emulsification and thickening, emulsion from damaging stratum, and according to the property of oil layer fluid, combining treatment agents such as inverse emulsifier, mutual solvent, etc., to form working fluid (inverse emulsification solid-free completion fluid) with phase change and solubilization function which can be used in the well completion operation of ecuador and other oil wells. When the working fluid is contacted and mixed with stratum crude oil, the working fluid can be unfolded on an oil-water interface to replace film forming substances in the crude oil, the film strength is reduced to damage emulsion, oil-water separation is maintained, reverse emulsification of completion fluid is realized, and the wellbore working fluid is prevented from being contacted with the crude oil to generate emulsification in reservoir completion operation.
Example 1:
The oil field crude oil of the ecuador Andes belongs to light crude oil, and the water content is less than 30 percent. For Andes oilfield crude oil properties, an invert emulsion solids-free completion fluid formulation suitable for construction of the block is preferred from the ratios described in the present invention, as shown in table 1.
The preparation method of the inverse emulsion solid-free completion fluid comprises the following steps: firstly, preparing a potassium chloride saline solution with the mass concentration of 2% as a base solution, then sequentially adding a mutual solvent, an inverse emulsifier, a clay stabilizer, a corrosion inhibitor and a bactericide into the base solution, and uniformly mixing to obtain a well completion working solution (namely an inverse-emulsified solid-free well completion solution). Wherein the mutual solvent is diethylene glycol butyl ether, the inverse emulsifier is polyethylene polyamine polyoxypropylene polyoxyethylene ether AE401, the clay stabilizer is micromolecular polyamine MEA, the corrosion inhibitor is imidazoline G707-KLH, and the bactericide is glutaraldehyde.
Example 2:
The oil field crude oil of the ecuador Andes belongs to light crude oil, and the water content is less than 30 percent. For Andes oilfield crude oil properties, an invert emulsion solids-free completion fluid formulation suitable for construction of the block is preferred from the ratios described in the present invention, as shown in table 1.
The preparation method of the reverse-emulsified solid-free completion fluid provided by the embodiment comprises the following steps: firstly, preparing a potassium chloride saline solution with the mass concentration of 2% as a base solution, then sequentially adding a mutual solvent, an inverse emulsifier, a clay stabilizer, a corrosion inhibitor and a bactericide into the base solution, and uniformly mixing to obtain the well completion working solution. Wherein the mutual solvent is diethylene glycol butyl ether, the inverse emulsifier is polyethylene polyamine polyoxypropylene polyoxyethylene ether (AE 402), the clay stabilizer is cationic quaternary ammonium salt PTA, the corrosion inhibitor is imidazoline G707-KLH, and the bactericide is glutaraldehyde.
Example 3:
The oil field crude oil of the ecuador Andes belongs to light crude oil, and the water content is less than 30 percent. For Andes oilfield crude oil properties, an invert emulsion solids-free completion fluid formulation suitable for construction of the block is preferred from the ratios described in the present invention, as shown in table 1.
The preparation method provided by the embodiment comprises the following steps: firstly, preparing a potassium chloride saline solution with the mass concentration of 5% as a base solution, then sequentially adding a mutual solvent, an inverse emulsifier, a clay stabilizer, a corrosion inhibitor and a bactericide into the base solution, and uniformly mixing to obtain the well completion working solution. Wherein the mutual solvent is a mixture formed by mixing diethylene glycol butyl ether and isopropanol according to a mass ratio of 1:1, the inverse emulsifier is polyethylene polyamine polyoxypropylene polyoxyethylene ether (AE 402), the clay stabilizer is micromolecular polyamine MEA, the corrosion inhibitor is imidazolines G707-KLH, and the bactericide is glutaraldehyde.
Example 4:
The oil field crude oil of the ecuador Andes belongs to light crude oil, and the water content is less than 30 percent. For Andes oilfield crude oil properties, an invert emulsion solids-free completion fluid formulation suitable for construction of the block is preferred from the ratios described in the present invention, as shown in table 1.
The preparation method provided by the embodiment comprises the following steps: firstly, preparing a potassium chloride saline solution with the mass concentration of 20% as a base solution, then sequentially adding a mutual solvent, an inverse emulsifier, a clay stabilizer, a corrosion inhibitor and a bactericide into the base solution, and uniformly mixing to obtain the well completion working solution. Wherein the mutual solvent is diethylene glycol butyl ether and isopropanol which are mixed according to the mass ratio of 1:1 to obtain a mixture, the inverse emulsifier is polyethylene polyamine polyoxypropylene polyoxyethylene ether (AE 402), the clay stabilizer is polyepichlorohydrin-dimethylamine (PTA), the corrosion inhibitor is imidazolines G707-KLH, and the bactericide is glutaraldehyde.
Example 5:
The oil field crude oil of the ecuador Andes belongs to light crude oil, and the water content is less than 30 percent. For Andes oilfield crude oil properties, an invert emulsion solids-free completion fluid formulation suitable for construction of the block is preferred from the ratios described in the present invention, as shown in table 1.
The preparation method provided by the embodiment comprises the following steps: firstly, preparing a potassium chloride saline solution with the mass concentration of 20% as a base solution, then sequentially adding a mutual solvent, an inverse emulsifier, a clay stabilizer, a corrosion inhibitor and a bactericide into the base solution, and uniformly mixing to obtain the well completion working solution. Wherein the mutual solvent is a mixture formed by mixing diethylene glycol butyl ether and isopropanol according to a mass ratio of 1:1, the inverse emulsifier is polyethylene polyamine polyoxypropylene polyoxyethylene ether (AE 405), the clay stabilizer is polyepichlorohydrin-dimethylamine (PTA), the corrosion inhibitor is organic amine CA101, and the bactericide is glutaraldehyde.
Example 6:
The oil field crude oil of the ecuador Andes belongs to light crude oil, and the water content is less than 30 percent. For Andes oilfield crude oil properties, an invert emulsion solids-free completion fluid formulation suitable for construction of the block is preferred from the ratios described in the present invention, as shown in table 1.
The preparation method provided by the embodiment comprises the following steps: firstly, preparing a potassium chloride saline solution with the mass concentration of 20% as a base solution, then sequentially adding a mutual solvent, an inverse emulsifier, a clay stabilizer, a corrosion inhibitor and a bactericide into the base solution, and uniformly mixing to obtain the well completion working solution. Wherein the mutual solvent is diethylene glycol butyl ether, the inverse emulsifier is polyethylene polyamine polyoxypropylene polyoxyethylene ether (AE 405), the clay stabilizer is small cation PTA, the corrosion inhibitor is organic amine CA101, and the bactericide is glutaraldehyde.
Table 1Andes oil field completion fluid (invert emulsion solids-free completion fluid) formulation design
Completion fluid performance test: according to the API RP 42 recommended test standard and with reference to the method specified by the oil and gas industry standard SY5281-2000, crude oil and completion working fluid are added to a 50mL stoppered cylinder according to 25:75, 50:50, 75:25, respectively fully mixing the well completion working fluids obtained in the examples 1-6 with crude oil, keeping the temperature at a dehydration temperature (50 ℃) for 20 minutes, fully mixing, keeping the temperature at a constant temperature, standing, recording the dehydration amount at different times, simultaneously observing whether an interface is neat or not, and observing whether the dehydrated water is turbid or not, namely observing indexes such as separation degree or emulsification degree, oil-water separation degree, oil-water internal phase adhesion degree and the like of the well completion working fluids and the crude oil after being mixed, testing the compatibility of the well completion fluids and the crude oil, and evaluating whether the well completion fluids and the crude oil meet construction requirements. The evaluation and observation criteria after mixing refer to fig. 1, namely, according to the interface states, are respectively: clear edges, dispersion and irregular edges.
The compatibility of the completion fluids obtained in examples 1-6 with Andes field crude oil blends, i.e., water/oil/emulsion volumes over time, were evaluated in accordance with fig. 1, and the test results are shown in tables 2,3,4,5,6,7,8 and fig. 2,3,4,5,6 and 7, respectively. From tables 2-8, figures 2-7 show that the results of the reverse emulsification of example 3 and example 4 are optimal and can be used in the oilfield completion.
Table 2 results of aqueous phase volume testing after completion fluid and crude oil were mixed in three ratios
Table 3 shows test data of the completion fluid of example 1 after mixing with crude oil in three proportions
Table 4 shows the test data of the three proportions of the completion fluid and crude oil of example 2
Table 5 shows the test data of three proportions of the completion fluid and crude oil of example 3
Table 6 shows the test data of three proportions of the completion fluid and crude oil of example 4
Table 7 shows the test data of the three proportions of the completion fluid and crude oil of example 5
Table 8 shows the test data of the three proportions of the completion fluid and crude oil of example 6
Example 7:
The development time of the oil field of the ecuador Tambococha is longer, the crude oil of the stratum is sticky, and the water content is not equal to 30-90%. For Tambococha oilfield crude oil properties, an invert emulsion solids-free completion fluid formulation suitable for this block construction is preferred from the ratios described in the present invention, as shown in table 9.
The preparation method of the reverse-emulsified solid-free completion fluid provided by the embodiment comprises the following steps: firstly, preparing sodium formate aqueous solution with the mass concentration of 2% as base solution, then sequentially adding a mutual solvent, an inverse emulsifier, a clay stabilizer, a corrosion inhibitor and a bactericide into the base solution, and uniformly mixing to obtain a well completion working solution (namely, an inverse-emulsified solid-free well completion solution). Wherein the mutual solvent is isopropanol and ethanol according to the mass ratio of 1:1, wherein the inverse emulsifier is alkyl phenolic resin polyoxypropylene polyoxyethylene ether AR101, the clay stabilizer is polyepoxy chloropropane-dimethylamine (PTA), the corrosion inhibitor is imidazoline G707-KLH, and the bactericide is glutaraldehyde.
Table 9 shows the formulation of Tambococha oilfield invert emulsion solids-free completion fluid
Example 8:
The development time of the oil field of the ecuador Tambococha is longer, the crude oil of the stratum is sticky, and the water content is not equal to 30-90%. For Tambococha oilfield crude oil properties, an invert emulsion solids-free completion fluid formulation suitable for this block construction is preferred from the ratios described in the present invention, as shown in table 9.
The preparation method of the reverse-emulsified solid-free completion fluid provided by the embodiment comprises the following steps: firstly, preparing sodium formate aqueous solution with the mass concentration of 2% as base solution, then sequentially adding a mutual solvent, an inverse emulsifier, a clay stabilizer, a corrosion inhibitor and a bactericide into the base solution, and uniformly mixing to obtain the well completion working solution. Wherein the mutual solvent is isopropanol and ethanol according to the mass ratio of 1:1, wherein the inverse emulsifier is alkyl phenolic resin polyoxypropylene polyoxyethylene ether AR102, the clay stabilizer is polyepoxy chloropropane-dimethylamine (PTA), the corrosion inhibitor is organic amine CA101, and the bactericide is glutaraldehyde.
Example 9:
The development time of the oil field of the ecuador Tambococha is longer, the crude oil of the stratum is sticky, and the water content is not equal to 30-90%. For Tambococha oilfield crude oil properties, an invert emulsion solids-free completion fluid formulation suitable for this block construction is preferred from the ratios described in the present invention, as shown in table 9.
The preparation method provided by the embodiment comprises the following steps: firstly, preparing sodium formate aqueous solution with the mass concentration of 2% as base solution, then sequentially adding a mutual solvent, an inverse emulsifier, a clay stabilizer, a corrosion inhibitor and a bactericide into the base solution, and uniformly mixing to obtain the well completion working solution. Wherein the mutual solvent is diethylene glycol butyl ether, the inverse emulsifier is alkyl phenolic resin polyoxypropylene polyoxyethylene ether AR102, the clay stabilizer is polyepichlorohydrin-dimethylamine (PTA), the corrosion inhibitor is imidazoline G707-KLH, and the bactericide is glutaraldehyde.
Example 10:
The development time of the oil field of the ecuador Tambococha is longer, the crude oil of the stratum is sticky, and the water content is not equal to 30-90%. For Tambococha oilfield crude oil properties, an invert emulsion solids-free completion fluid formulation suitable for this block construction is preferred from the ratios described in the present invention, as shown in table 9.
The preparation method provided by the embodiment comprises the following steps: firstly, preparing sodium formate aqueous solution with the mass concentration of 2% as base solution, then sequentially adding a mutual solvent, an inverse emulsifier, a clay stabilizer, a corrosion inhibitor and a bactericide into the base solution, and uniformly mixing to obtain the well completion working solution. Wherein the mutual solvent is diethylene glycol butyl ether, the inverse emulsifier is alkyl phenolic resin polyoxypropylene polyoxyethylene ether AR103, the clay stabilizer is polyepichlorohydrin-dimethylamine (PTA), the corrosion inhibitor is imidazolines G707-KLH, and the bactericide is glutaraldehyde.
Example 11:
The development time of the oil field of the ecuador Tambococha is longer, the crude oil of the stratum is sticky, and the water content is not equal to 30-90%. For Tambococha oilfield crude oil properties, an invert emulsion solids-free completion fluid formulation suitable for this block construction is preferred from the ratios described in the present invention, as shown in table 9.
The preparation method provided by the embodiment comprises the following steps: firstly, preparing sodium formate aqueous solution with the mass concentration of 2% as base solution, then sequentially adding a mutual solvent, an inverse emulsifier, a clay stabilizer, a corrosion inhibitor and a bactericide into the base solution, and uniformly mixing to obtain the well completion working solution. Wherein the mutual solvent is diethylene glycol butyl ether, the inverse emulsifier is alkyl phenolic resin polyoxypropylene polyoxyethylene ether AR103, the clay stabilizer is polyepichlorohydrin-dimethylamine (PTA), the corrosion inhibitor is organic amine CA101, and the bactericide is glutaraldehyde.
Example 12:
The development time of the oil field of the ecuador Tambococha is longer, the crude oil of the stratum is sticky, and the water content is not equal to 30-90%. For Tambococha oilfield crude oil properties, an invert emulsion solids-free completion fluid formulation suitable for this block construction is preferred from the ratios described in the present invention, as shown in table 9.
The preparation method provided by the embodiment comprises the following steps: firstly, preparing sodium formate aqueous solution with the mass concentration of 2% as base solution, then sequentially adding a mutual solvent, an inverse emulsifier, a clay stabilizer, a corrosion inhibitor and a bactericide into the base solution, and uniformly mixing to obtain the well completion working solution. Wherein the mutual solvent is isopropanol, the inverse emulsifier is alkyl phenolic resin polyoxypropylene polyoxyethylene ether AR103, the clay stabilizer is micromolecular polyamine MEA, the corrosion inhibitor is organic amine CA101, and the bactericide is glutaraldehyde.
Completion fluid performance test: according to the API RP 42 recommended test standard and referring to a method specified by the petroleum and natural gas industry standard SY5281-2000, 100mL of water-containing thickened oil is preheated, 100mL of well completion working fluid obtained in examples 7-12 is respectively mixed in a 250mL wide-mouth bottle, the mixture is fully mixed after being kept at a constant temperature of dehydration temperature (60 ℃) for 30 minutes, the mixture is kept at the constant temperature, the dehydration amount at different times is recorded, meanwhile, whether interfaces are orderly or not is observed, whether the dehydrated water is turbid or not is observed, namely indexes such as separation degree or emulsification degree, oil-water separation degree, oil-water internal phase adhesion degree and the like after the completion fluid and crude oil are mixed are observed, and whether the completion meets construction requirements or not is evaluated.
The completion fluids obtained in examples 7-12 were evaluated for mixing with Tambococha field crude oil and the test results are shown in Table 10, FIG. 8, FIG. 9, FIG. 10, FIG. 11, FIG. 12 and FIG. 13. From the test results, the formula of the embodiment 8 has the advantages of optimal reverse emulsification result and minimum separation time, and can be used for the completion operation of the oil field.
Table 10 data on oil-water phase separation after completion fluid and crude oil are mixed
| Time, min | Example 7 | Example 8 | Example 9 | Example 10 | Example 11 | Example 12 |
| 0 | 30％ | 30％ | 30％ | 30％ | 30％ | 50％ |
| 5 | 30％ | 30％ | 50％ | 60％ | 70％ | 50％ |
| 10 | 70％ | 90％ | 50％ | 60％ | 70％ | 60％ |
| 15 | 70％ | 100％ | 80％ | 60％ | 70％ | 60％ |
| 20 | 70％ | 100％ | 90％ | 60％ | 70％ | 60％ |
| 25 | 70％ | 100％ | 90％ | 60％ | 70％ | 60％ |
| 30 | 70％ | 100％ | 90％ | 60％ | 70％ | 60％ |
| 45 | 70％ | 100％ | 100％ | 60％ | 70％ | 60％ |
| 60 | 70％ | 100％ | 100％ | 60％ | 70％ | 60％ |
| 180(3h) | 80％ | 100％ | 100％ | 70％ | 80％ | 100％ |
| 1440(24h) | 80％ | 100％ | 100％ | 70％ | 80％ | 100％ |
| Final degree of separation | 80％ | 100％ | 100％ | 70％ | 80％ | 100％ |
| Separation time, min | 180 | 15 | 45 | 180 | 180 | 180 |
| Interface shape | Irregularities | Clear and clear | Clear and clear | Irregularities | Irregularities | Clear and clear |
| Degree of aqueous phase adhesion | In (a) | Low and low | Without any means for | Low and low | In (a) | In (a) |
| Degree of oil phase adhesion | In (a) | Low and low | Low and low | High height | High height | High height |
| Color of aqueous phase | Light brown | Colorless and colorless | Light brown | Light brown | Light brown | Colorless and colorless |
In summary, after the completion working fluid (i.e. the reverse-emulsified solid-free completion fluid) is contacted and mixed with the crude oil of the stratum, the completion working fluid can be unfolded on an oil-water interface to replace film forming substances in the crude oil, so that the emulsion is destroyed due to the reduction of the film strength, the oil-water separation is maintained, the reverse emulsification effect of the completion working fluid is realized, the wellbore working fluid is prevented from being emulsified due to the contact of the wellbore working fluid and the crude oil in the reservoir completion operation, and the damage of the emulsion and the solid phase to the high-porosity stratum due to the thickening of the wellbore fluid, the increase of the viscosity, the difficulty in pumping and the blockage of an oil well are avoided. Therefore, the well completion working fluid has the advantages of good rheological property, small circulating friction and pressure loss in the construction process, simple field preparation, low cost and the like, and is particularly suitable for well completion operation of directional wells and horizontal wells of high-permeability and high-yield reservoirs of ecuador and other basins like the ecuador Oriente.
The methods not described in detail in the above embodiments are common general knowledge in the industry and are not described here. The related materials or finished products are all commercial products.
The foregoing examples are merely illustrative of the present invention and are not intended to limit the scope of the present invention, and all designs that are the same or similar to the present invention are within the scope of the present invention.
Claims (4)
1. An inverse emulsion solid-free completion fluid, which is characterized in that: comprises monovalent brine, 0.05 to 0.5 percent of mutual solvent, 0.05 to 1.0 percent of inverse emulsifier, 0.5 to 2.0 percent of clay stabilizer, 0 to 0.5 percent of corrosion inhibitor and 0 to 0.5 percent of bactericide according to the volume of the monovalent brine;
the monovalent brine is one or a mixture of potassium chloride aqueous solution and sodium formate aqueous solution; and the mass concentration of monovalent salt water is 1.0-30%;
The mutual solvent is one or a mixture of more of isopropanol, ethanol and diethylene glycol butyl ether;
The inverse emulsifier is any one of alkyl phenolic resin polyoxypropylene polyoxyethylene ether and polyethylene polyamine polyoxypropylene polyoxyethylene ether;
the clay stabilizer is cationic quaternary ammonium salt;
The corrosion inhibitor is an amine corrosion inhibitor and an imidazoline corrosion inhibitor; wherein the amine corrosion inhibitor is one of organic amine CA101, dodecyl amine, long-chain quaternary amine and alkoxyamine; the imidazoline type corrosion inhibitor is a compound imidazoline type corrosion inhibitor, and comprises 20-30% of heptadecyl hydroxyethyl imidazoline, 10-20% of sodium benzoate, 5-10% of zinc sulfate heptahydrate, 5-10% of sodium molybdate and 30-60% of water by mass concentration;
the bactericide is glutaraldehyde.
2. The inverse emulsion solids free completion fluid of claim 1, wherein: the cationic quaternary ammonium salt is one of dimethyl diallyl ammonium chloride, polyepichlorohydrin-dimethylamine and cocoamidomethyl MEA.
3. A method of preparing an inverse emulsion solids-free completion fluid according to any one of claims 1-2, comprising the steps of:
S1, preparing monovalent salt water: mixing one or two of potassium chloride and sodium formate with clear water, and stirring until the mixture is completely dissolved to prepare monovalent salt water with the mass concentration of 1-30%;
S2, adding 0.05 to 0.5 percent of mutual solvent, 0.05 to 1.0 percent of inverse emulsifier, 0.5 to 2.0 percent of clay stabilizer, 0 to 0.5 percent of corrosion inhibitor and 0 to 0.5 percent of bactericide which are calculated by the volume of the monovalent brine into the monovalent brine prepared in the step S1 under the condition of normal temperature and normal pressure, and uniformly mixing to obtain the completion working fluid.
4. Use of an inverse emulsion solids-free completion fluid according to any of claims 1-2, characterized in that: the inverse emulsion solid-free completion fluid is used for casing completion, open hole completion or screen pipe completion; when the well completion fluid is used for casing well completion, the well completion fluid comprises monovalent brine, 0.1 to 0.5 percent of mutual solvent, 0.1 to 1.0 percent of inverse emulsifier, 1.0 to 2.0 percent of clay stabilizer, 0 to 0.5 percent of corrosion inhibitor and 0 to 0.5 percent of bactericide according to the volume of the monovalent brine; when the well completion fluid is used for open hole or screen pipe well completion, the well completion fluid comprises 0.1-0.5% of a mutual solvent, 0.1-1.0% of an inverse emulsifier and 1.0-2.0% of a clay stabilizer by the volume of monovalent brine.
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