CN114381282A - Surfactant and preparation method thereof, microemulsion plugging agent and preparation method thereof, and water-based drilling fluid - Google Patents
Surfactant and preparation method thereof, microemulsion plugging agent and preparation method thereof, and water-based drilling fluid Download PDFInfo
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- CN114381282A CN114381282A CN202111552870.6A CN202111552870A CN114381282A CN 114381282 A CN114381282 A CN 114381282A CN 202111552870 A CN202111552870 A CN 202111552870A CN 114381282 A CN114381282 A CN 114381282A
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- surfactant
- water
- microemulsion
- drilling fluid
- plugging agent
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- 239000004530 micro-emulsion Substances 0.000 title claims abstract description 91
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 85
- 238000005553 drilling Methods 0.000 title claims abstract description 73
- 239000012530 fluid Substances 0.000 title claims abstract description 71
- 239000004094 surface-active agent Substances 0.000 title claims abstract description 67
- 239000003795 chemical substances by application Substances 0.000 title claims abstract description 55
- 238000002360 preparation method Methods 0.000 title claims abstract description 26
- 239000012267 brine Substances 0.000 claims abstract description 37
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 claims abstract description 37
- -1 amine hydrochloride Chemical class 0.000 claims abstract description 30
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 claims abstract description 21
- 238000000034 method Methods 0.000 claims abstract description 21
- 230000000694 effects Effects 0.000 claims abstract description 14
- 239000011780 sodium chloride Substances 0.000 claims abstract description 14
- 150000008053 sultones Chemical class 0.000 claims abstract description 13
- SNRUBQQJIBEYMU-UHFFFAOYSA-N Dodecane Natural products CCCCCCCCCCCC SNRUBQQJIBEYMU-UHFFFAOYSA-N 0.000 claims abstract description 10
- 238000002156 mixing Methods 0.000 claims abstract description 9
- 238000005956 quaternization reaction Methods 0.000 claims abstract description 9
- 238000007142 ring opening reaction Methods 0.000 claims abstract description 9
- 238000006277 sulfonation reaction Methods 0.000 claims abstract description 7
- 239000004064 cosurfactant Substances 0.000 claims abstract description 6
- LRWZZZWJMFNZIK-UHFFFAOYSA-N 2-chloro-3-methyloxirane Chemical compound CC1OC1Cl LRWZZZWJMFNZIK-UHFFFAOYSA-N 0.000 claims abstract description 4
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims description 52
- WYURNTSHIVDZCO-UHFFFAOYSA-N Tetrahydrofuran Chemical compound C1CCOC1 WYURNTSHIVDZCO-UHFFFAOYSA-N 0.000 claims description 34
- 239000002904 solvent Substances 0.000 claims description 23
- 239000000243 solution Substances 0.000 claims description 18
- 239000007788 liquid Substances 0.000 claims description 16
- YLQBMQCUIZJEEH-UHFFFAOYSA-N tetrahydrofuran Natural products C=1C=COC=1 YLQBMQCUIZJEEH-UHFFFAOYSA-N 0.000 claims description 16
- BRLQWZUYTZBJKN-UHFFFAOYSA-N Epichlorohydrin Chemical compound ClCC1CO1 BRLQWZUYTZBJKN-UHFFFAOYSA-N 0.000 claims description 12
- 125000002496 methyl group Chemical group [H]C([H])([H])* 0.000 claims description 12
- 125000004123 n-propyl group Chemical group [H]C([H])([H])C([H])([H])C([H])([H])* 0.000 claims description 12
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical compound [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 claims description 11
- LRHPLDYGYMQRHN-UHFFFAOYSA-N N-Butanol Chemical compound CCCCO LRHPLDYGYMQRHN-UHFFFAOYSA-N 0.000 claims description 10
- 239000002245 particle Substances 0.000 claims description 10
- NWGKJDSIEKMTRX-AAZCQSIUSA-N Sorbitan monooleate Chemical compound CCCCCCCC\C=C/CCCCCCCC(=O)OC[C@@H](O)[C@H]1OC[C@H](O)[C@H]1O NWGKJDSIEKMTRX-AAZCQSIUSA-N 0.000 claims description 9
- 239000012071 phase Substances 0.000 claims description 9
- BBMCTIGTTCKYKF-UHFFFAOYSA-N 1-heptanol Chemical compound CCCCCCCO BBMCTIGTTCKYKF-UHFFFAOYSA-N 0.000 claims description 8
- AMQJEAYHLZJPGS-UHFFFAOYSA-N N-Pentanol Chemical compound CCCCCO AMQJEAYHLZJPGS-UHFFFAOYSA-N 0.000 claims description 8
- 239000002283 diesel fuel Substances 0.000 claims description 8
- ZSIAUFGUXNUGDI-UHFFFAOYSA-N hexan-1-ol Chemical compound CCCCCCO ZSIAUFGUXNUGDI-UHFFFAOYSA-N 0.000 claims description 8
- 238000010992 reflux Methods 0.000 claims description 8
- 229910052708 sodium Inorganic materials 0.000 claims description 8
- 239000011734 sodium Substances 0.000 claims description 8
- XHFGWHUWQXTGAT-UHFFFAOYSA-N dimethylamine hydrochloride Natural products CNC(C)C XHFGWHUWQXTGAT-UHFFFAOYSA-N 0.000 claims description 7
- IQDGSYLLQPDQDV-UHFFFAOYSA-N dimethylazanium;chloride Chemical compound Cl.CNC IQDGSYLLQPDQDV-UHFFFAOYSA-N 0.000 claims description 7
- 229910052744 lithium Inorganic materials 0.000 claims description 6
- 229910052700 potassium Inorganic materials 0.000 claims description 6
- FSSPGSAQUIYDCN-UHFFFAOYSA-N 1,3-Propane sultone Chemical group O=S1(=O)CCCO1 FSSPGSAQUIYDCN-UHFFFAOYSA-N 0.000 claims description 5
- 238000001704 evaporation Methods 0.000 claims description 5
- 239000001103 potassium chloride Substances 0.000 claims description 5
- 235000011164 potassium chloride Nutrition 0.000 claims description 5
- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 claims description 4
- DIOQZVSQGTUSAI-UHFFFAOYSA-N decane Chemical compound CCCCCCCCCC DIOQZVSQGTUSAI-UHFFFAOYSA-N 0.000 claims description 4
- 238000004821 distillation Methods 0.000 claims description 4
- GAZIBGHLWYHBDT-UHFFFAOYSA-N n-propylpropan-1-amine;hydrochloride Chemical compound Cl.CCCNCCC GAZIBGHLWYHBDT-UHFFFAOYSA-N 0.000 claims description 4
- TVMXDCGIABBOFY-UHFFFAOYSA-N octane Chemical compound CCCCCCCC TVMXDCGIABBOFY-UHFFFAOYSA-N 0.000 claims description 4
- MHYFEEDKONKGEB-UHFFFAOYSA-N oxathiane 2,2-dioxide Chemical compound O=S1(=O)CCCCO1 MHYFEEDKONKGEB-UHFFFAOYSA-N 0.000 claims description 4
- CBPYOHALYYGNOE-UHFFFAOYSA-M potassium;3,5-dinitrobenzoate Chemical compound [K+].[O-]C(=O)C1=CC([N+]([O-])=O)=CC([N+]([O-])=O)=C1 CBPYOHALYYGNOE-UHFFFAOYSA-M 0.000 claims description 4
- BDERNNFJNOPAEC-UHFFFAOYSA-N propan-1-ol Chemical compound CCCO BDERNNFJNOPAEC-UHFFFAOYSA-N 0.000 claims description 4
- 239000004280 Sodium formate Substances 0.000 claims description 3
- 239000008346 aqueous phase Substances 0.000 claims description 3
- 239000001110 calcium chloride Substances 0.000 claims description 3
- 229910001628 calcium chloride Inorganic materials 0.000 claims description 3
- 150000001875 compounds Chemical class 0.000 claims description 3
- WFIZEGIEIOHZCP-UHFFFAOYSA-M potassium formate Chemical compound [K+].[O-]C=O WFIZEGIEIOHZCP-UHFFFAOYSA-M 0.000 claims description 3
- HLBBKKJFGFRGMU-UHFFFAOYSA-M sodium formate Chemical compound [Na+].[O-]C=O HLBBKKJFGFRGMU-UHFFFAOYSA-M 0.000 claims description 3
- 235000019254 sodium formate Nutrition 0.000 claims description 3
- DNIAPMSPPWPWGF-VKHMYHEASA-N (+)-propylene glycol Chemical compound C[C@H](O)CO DNIAPMSPPWPWGF-VKHMYHEASA-N 0.000 claims description 2
- YPFDHNVEDLHUCE-UHFFFAOYSA-N 1,3-propanediol Substances OCCCO YPFDHNVEDLHUCE-UHFFFAOYSA-N 0.000 claims description 2
- 229940035437 1,3-propanediol Drugs 0.000 claims description 2
- QKDFWYFCMLUTQD-UHFFFAOYSA-N 17-bromo-N,N-dimethylheptadecan-1-amine Chemical compound BrCCCCCCCCCCCCCCCCCN(C)C QKDFWYFCMLUTQD-UHFFFAOYSA-N 0.000 claims description 2
- 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 2
- 229910019142 PO4 Inorganic materials 0.000 claims description 2
- 239000002202 Polyethylene glycol Substances 0.000 claims description 2
- 239000004721 Polyphenylene oxide Substances 0.000 claims description 2
- 125000005010 perfluoroalkyl group Chemical group 0.000 claims description 2
- NBIIXXVUZAFLBC-UHFFFAOYSA-K phosphate Chemical compound [O-]P([O-])([O-])=O NBIIXXVUZAFLBC-UHFFFAOYSA-K 0.000 claims description 2
- 239000010452 phosphate Substances 0.000 claims description 2
- 229920000570 polyether Polymers 0.000 claims description 2
- 229920001223 polyethylene glycol Polymers 0.000 claims description 2
- 235000010482 polyoxyethylene sorbitan monooleate Nutrition 0.000 claims description 2
- 229920000053 polysorbate 80 Polymers 0.000 claims description 2
- 229920000166 polytrimethylene carbonate Polymers 0.000 claims description 2
- 150000003512 tertiary amines Chemical class 0.000 claims description 2
- 230000005764 inhibitory process Effects 0.000 abstract description 10
- 230000000087 stabilizing effect Effects 0.000 abstract description 3
- 239000003208 petroleum Substances 0.000 abstract description 2
- CSCPPACGZOOCGX-UHFFFAOYSA-N Acetone Chemical compound CC(C)=O CSCPPACGZOOCGX-UHFFFAOYSA-N 0.000 description 14
- 238000012360 testing method Methods 0.000 description 10
- 238000006243 chemical reaction Methods 0.000 description 8
- 239000000839 emulsion Substances 0.000 description 8
- 239000000203 mixture Substances 0.000 description 7
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical group OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 description 6
- YXFVVABEGXRONW-UHFFFAOYSA-N Toluene Chemical compound CC1=CC=CC=C1 YXFVVABEGXRONW-UHFFFAOYSA-N 0.000 description 6
- 238000011160 research Methods 0.000 description 6
- 239000011435 rock Substances 0.000 description 5
- 239000006185 dispersion Substances 0.000 description 4
- 239000000463 material Substances 0.000 description 4
- VLKZOEOYAKHREP-UHFFFAOYSA-N n-Hexane Chemical compound CCCCCC VLKZOEOYAKHREP-UHFFFAOYSA-N 0.000 description 4
- 238000011084 recovery Methods 0.000 description 4
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 description 3
- RWCCWEUUXYIKHB-UHFFFAOYSA-N benzophenone Chemical compound C=1C=CC=CC=1C(=O)C1=CC=CC=C1 RWCCWEUUXYIKHB-UHFFFAOYSA-N 0.000 description 3
- 239000012965 benzophenone Substances 0.000 description 3
- 239000004927 clay Substances 0.000 description 3
- 230000001804 emulsifying effect Effects 0.000 description 3
- 238000005516 engineering process Methods 0.000 description 3
- 238000001914 filtration Methods 0.000 description 3
- 230000002401 inhibitory effect Effects 0.000 description 3
- 239000012046 mixed solvent Substances 0.000 description 3
- 239000000047 product Substances 0.000 description 3
- 230000008961 swelling Effects 0.000 description 3
- VTYYLEPIZMXCLO-UHFFFAOYSA-L Calcium carbonate Chemical compound [Ca+2].[O-]C([O-])=O VTYYLEPIZMXCLO-UHFFFAOYSA-L 0.000 description 2
- 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 description 2
- 239000008186 active pharmaceutical agent Substances 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 2
- 239000000440 bentonite Substances 0.000 description 2
- 229910000278 bentonite Inorganic materials 0.000 description 2
- SVPXDRXYRYOSEX-UHFFFAOYSA-N bentoquatam Chemical compound O.O=[Si]=O.O=[Al]O[Al]=O SVPXDRXYRYOSEX-UHFFFAOYSA-N 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 2
- 239000007810 chemical reaction solvent Substances 0.000 description 2
- 238000002474 experimental method Methods 0.000 description 2
- 239000012847 fine chemical Substances 0.000 description 2
- 239000013505 freshwater Substances 0.000 description 2
- 238000005098 hot rolling Methods 0.000 description 2
- 230000036571 hydration Effects 0.000 description 2
- 238000006703 hydration reaction Methods 0.000 description 2
- 238000005259 measurement Methods 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 239000003607 modifier Substances 0.000 description 2
- 239000007908 nanoemulsion Substances 0.000 description 2
- 238000011085 pressure filtration Methods 0.000 description 2
- 239000002002 slurry Substances 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- 208000028990 Skin injury Diseases 0.000 description 1
- TZCXTZWJZNENPQ-UHFFFAOYSA-L barium sulfate Chemical compound [Ba+2].[O-]S([O-])(=O)=O TZCXTZWJZNENPQ-UHFFFAOYSA-L 0.000 description 1
- 239000010428 baryte Substances 0.000 description 1
- 229910052601 baryte Inorganic materials 0.000 description 1
- 229910000019 calcium carbonate Inorganic materials 0.000 description 1
- 238000005119 centrifugation Methods 0.000 description 1
- 239000013043 chemical agent Substances 0.000 description 1
- 230000000052 comparative effect Effects 0.000 description 1
- 230000006378 damage Effects 0.000 description 1
- 230000007423 decrease Effects 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 239000002270 dispersing agent Substances 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 230000008020 evaporation Effects 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 239000000706 filtrate Substances 0.000 description 1
- 238000009472 formulation Methods 0.000 description 1
- 230000002209 hydrophobic effect Effects 0.000 description 1
- 125000002887 hydroxy group Chemical group [H]O* 0.000 description 1
- 230000035515 penetration Effects 0.000 description 1
- 239000004033 plastic Substances 0.000 description 1
- 229920003023 plastic Polymers 0.000 description 1
- 229920000768 polyamine Polymers 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 239000003223 protective agent Substances 0.000 description 1
- 238000000746 purification Methods 0.000 description 1
- 238000005096 rolling process Methods 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 239000009671 shengli Substances 0.000 description 1
- 239000002689 soil Substances 0.000 description 1
- 230000003381 solubilizing effect Effects 0.000 description 1
- 238000001179 sorption measurement Methods 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 238000009736 wetting Methods 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C07—ORGANIC CHEMISTRY
- C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
- C07C213/00—Preparation of compounds containing amino and hydroxy, amino and etherified hydroxy or amino and esterified hydroxy groups bound to the same carbon skeleton
- C07C213/04—Preparation of compounds containing amino and hydroxy, amino and etherified hydroxy or amino and esterified hydroxy groups bound to the same carbon skeleton by reaction of ammonia or amines with olefin oxides or halohydrins
-
- C—CHEMISTRY; METALLURGY
- C07—ORGANIC CHEMISTRY
- C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
- C07C213/00—Preparation of compounds containing amino and hydroxy, amino and etherified hydroxy or amino and esterified hydroxy groups bound to the same carbon skeleton
- C07C213/08—Preparation of compounds containing amino and hydroxy, amino and etherified hydroxy or amino and esterified hydroxy groups bound to the same carbon skeleton by reactions not involving the formation of amino groups, hydroxy groups or etherified or esterified hydroxy groups
-
- C—CHEMISTRY; METALLURGY
- C07—ORGANIC CHEMISTRY
- C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
- C07C303/00—Preparation of esters or amides of sulfuric acids; Preparation of sulfonic acids or of their esters, halides, anhydrides or amides
- C07C303/26—Preparation of esters or amides of sulfuric acids; Preparation of sulfonic acids or of their esters, halides, anhydrides or amides of esters of sulfonic acids
- C07C303/28—Preparation of esters or amides of sulfuric acids; Preparation of sulfonic acids or of their esters, halides, anhydrides or amides of esters of sulfonic acids by reaction of hydroxy compounds with sulfonic acids or derivatives thereof
-
- 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
- C09K8/03—Specific additives for general use in well-drilling compositions
- C09K8/035—Organic additives
-
- 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
- C09K8/14—Clay-containing compositions
- C09K8/18—Clay-containing compositions characterised by the organic compounds
- C09K8/22—Synthetic organic compounds
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
- C09K8/426—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells for plugging
-
- 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
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/10—Nanoparticle-containing well treatment 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
Landscapes
- Chemical & Material Sciences (AREA)
- Organic Chemistry (AREA)
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Materials Engineering (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Dispersion Chemistry (AREA)
- Colloid Chemistry (AREA)
Abstract
The invention relates to the field of petroleum engineering, and discloses a surfactant and a preparation method thereof, a microemulsion plugging agent and a preparation method thereof, and a water-based drilling fluid. The preparation method of the surfactant comprises the following steps: (1) carrying out ring-opening reaction on amine hydrochloride and epoxy chloropropane to obtain a first intermediate; (2) carrying out quaternization reaction on the first intermediate and dodecyl dimethyl tertiary amine to obtain a second intermediate; (3) and carrying out sulfonation reaction on the second intermediate, sultone and MH to obtain the surfactant. The preparation method of the microemulsion plugging agent comprises the following steps: mixing an oil phase, brine, a first surfactant, a second surfactant and a cosurfactant to obtain the microemulsion plugging agent; wherein the first surfactant is prepared by the method, and the water phase activity of the saline water is not more than 0.85. The microemulsion plugging agent for the water-based drilling fluid provided by the invention has a good well wall stabilizing effect, and realizes the unification of strong inhibition and strong plugging performances.
Description
Technical Field
The invention relates to the field of petroleum engineering, in particular to a surfactant and a preparation method thereof, a microemulsion plugging agent and a preparation method thereof, and a water-based drilling fluid.
Background
Since the first discovery of Hoar and Schulman in 1943, the research on theory and application of microemulsion (microemulsion/ME) has made great progress, and after the world oil crisis occurred in the 20 th century 70 s, the development of microemulsion systems has been advanced due to the enormous potential shown in tertiary oil recovery technology. After 90 s, the application field of the microemulsion is rapidly expanded, and the microemulsion has permeated the fields of daily chemical industry, fine chemical industry, material science, biotechnology, environmental science, analytical chemistry and the like in addition to the 3-time oil extraction technology, and becomes a popular research field with huge potential in the world at present.
Since the new century, more and more oil companies have come to notice the great value of microemulsions, have conducted intensive research on microemulsions and have broadened their application fields. The Haributton energy company develops a microemulsion technology which can remove the emulsion blockage and invert the reservoir wettability into water wetting again, thereby achieving the purpose of effectively repairing the formation damage. The research on the blockage removal of the microemulsion is also carried out by the Beckhols company, and the microemulsion can be used for solubilizing the solvent oil in the mud cake on the well wall and enabling the particles in the mud cake to be inverted into hydrophilicity, so that the purpose of removing the skin injury is achieved. In a TERRA-MAXHPWBM (high-performance water-based drilling fluid) system constructed by Beckhous, an emulsion technology is used for plugging micro/nano pores of shale, so that the purposes of achieving good well wall stability and clay dispersion inhibition, reducing torque and friction resistance, improving drilling speed and reducing total cost are achieved.
The microemulsion reservoir protective agent is developed in the first place abroad, is successfully applied to shale gas drilling and yield increasing measures, and is beneficial to improving the yield of gas wells. However, the research on related aspects in China is still in the initial stage, and the conventional microemulsion generally adopts fresh water or low-concentration saline water, and the microemulsion is difficult to form under the high-concentration saline water.
Disclosure of Invention
The invention aims to solve the problems of poor salt resistance, inapplicability in a low-activity drilling fluid system and the like of the conventional microemulsion system, and provides a surfactant and a preparation method thereof, a microemulsion plugging agent and a preparation method thereof and a water-based drilling fluid.
In order to achieve the above object, the first aspect of the present invention provides a surfactant, wherein the structure of the surfactant is represented by structural formula I.
Wherein R is1is-CH3、-CH2CH3or-CH2CH2CH3，R2is-CH3、-CH2CH3or-CH2CH2CH3，R3Is- (CH)2)3-or- (CH)2)4-，R4Is- (CH)2)3-or- (CH)2)4-，M1Is Li, Na or K, M2Is Li, Na or K.
The second aspect of the invention provides a preparation method of the surfactant. The method comprises the following steps:
(1) carrying out ring-opening reaction on amine hydrochloride shown in a formula II and epoxy chloropropane to obtain a first intermediate;
(2) Carrying out quaternization reaction on the first intermediate and dodecyl dimethyl tertiary amine to obtain a second intermediate;
(3) carrying out sulfonation reaction on the second intermediate, sultone shown in a formula III and a compound shown in a general formula MH to obtain the surfactant,
In a third aspect, the present invention provides a surfactant obtained by the method of the second aspect.
The fourth aspect of the invention provides a preparation method of a microemulsion plugging agent for water-based drilling fluid, which comprises the following steps: mixing an oil phase, brine, a first surfactant, a second surfactant and a cosurfactant to obtain the microemulsion plugging agent; wherein the first surfactant is the surfactant according to the first aspect; the aqueous phase activity of the brine is no greater than 0.85.
In a fifth aspect, the invention provides a microemulsion plugging agent for water-based drilling fluid prepared by the method in the fourth aspect. The average grain diameter of the microemulsion plugging agent is 10-60 nm.
In a sixth aspect, the invention provides a water-based drilling fluid, which comprises the microemulsion plugging agent for the water-based drilling fluid in the fifth aspect.
Through the technical scheme, the invention can obtain the following beneficial effects:
(1) the microemulsion plugging agent for the water-based drilling fluid can be used for plugging micro-nano cracks with different sizes, and has good plugging performance;
(2) compared with the prior art, the microemulsion plugging agent for the water-based drilling fluid is prepared by adopting high-concentration brine, and the prepared microemulsion is used in the drilling fluid which has strong inhibition.
(3) The microemulsion liquid drop for the water-based drilling fluid provided by the invention can be quickly adsorbed on the surface of a rock core, so that the wettability of the rock core is changed from hydrophilic to hydrophobic, and the affinity to water molecules is reduced. Once the microemulsion liquid drops are demulsified, the internal saline is released, so that the hydration and dispersion of the clay can be further inhibited, and the microemulsion liquid drops have good inhibition performance.
Detailed Description
The endpoints of the ranges and any values disclosed herein are not limited to the precise range or value, and such ranges or values should be understood to encompass values close to those ranges or values. For ranges of values, between the endpoints of each of the ranges and the individual points, and between the individual points may be combined with each other to give one or more new ranges of values, and these ranges of values should be considered as specifically disclosed herein.
In the present invention, the terms "first" and "second" do not limit the present inventors, but are only used to distinguish different materials.
In a first aspect, the present invention provides a surfactant having a structure according to formula i.
Wherein R is1is-CH3、-CH2CH3or-CH2CH2CH3，R2is-CH3、-CH2CH3or-CH2CH2CH3，R3Is- (CH)2)3-or- (CH)2)4-，R4Is- (CH)2)3-or- (CH)2)4-，M1Is Li, Na or K, M2Is Li, Na or K.
In some embodiments of the invention, R1And R2Which may be the same or different, depending primarily on the amine hydrochloride used in the preparation.
In some embodiments of the invention, R3And R4Which may be the same or different, depends primarily on the sultone used in the preparation.
In some embodiments of the invention, M1And M2May be different or identical, preferably identical.
The second aspect of the invention provides a preparation method of the surfactant. The method comprises the following steps:
(1) carrying out ring-opening reaction on amine hydrochloride and epoxy chloropropane to obtain a first intermediate; the amine hydrochloride is shown as a formula II,
the reaction process of the ring-opening reaction is as follows:
wherein R is1is-CH3、-CH2CH3or-CH2CH2CH3，R2is-CH3、-CH2CH3or-CH2CH2CH3；
(2) Carrying out quaternization reaction on the first intermediate and dodecyl dimethyl tertiary amine to obtain a second intermediate; the reaction process of the quaternization reaction is as follows:
(3) carrying out sulfonation reaction on the second intermediate, sultone and a compound represented by a general formula MH to obtain the surfactant, wherein the sultone is represented by a formula III,
the reaction process of the sulfonation reaction is as follows:
wherein R is3Is- (CH)2)3-or- (CH)2)4-MH is one or two of LiH, NaH and KH.
In some embodiments of the invention, the ring-opening reaction is carried out in the presence of a first solvent; preferably, step (1) further comprises: dissolving amine hydrochloride and epichlorohydrin in the first solvent; and carrying out reduced pressure distillation on the product solution obtained by the ring-opening reaction to remove the first solvent, so as to obtain the first intermediate.
In the present invention, the first solvent is not particularly limited as long as the amine hydrochloride and the epichlorohydrin are dissolved. Preferably, the first solvent is selected from methanol, ethanol, acetone, toluene, preferably ethanol.
The amount of ethanol used as a solvent for dissolving the amine hydrochloride and the epichlorohydrin is not particularly limited, and the amine hydrochloride and the epichlorohydrin can be completely dissolved. Preferably, in the ethanol solution of amine hydrochloride, the mass ratio of the amine hydrochloride to the ethanol is 1:5-1:20, preferably 1:8-1:15, more preferably 1:8-1: 12; in the ethanol solution of the epichlorohydrin, the mass ratio of the epichlorohydrin to the ethanol is 1:0.5-1:5, preferably 1:0.5-1:3, and more preferably 1:0.5-1: 1.2.
In some embodiments of the invention, the amine hydrochloride is selected from one or more of dimethylamine hydrochloride, diethylamine hydrochloride, and dipropylamine hydrochloride.
In some embodiments of the present invention, in order to ensure sufficient reaction between the amine hydrochloride and the epichlorohydrin, the mass ratio of the amine hydrochloride to the epichlorohydrin is 1:1 to 1:5, preferably 1:1 to 1:4, and more preferably 1:1.3 to 1: 3.
In some embodiments of the invention, the quaternization reaction is carried out in the presence of a second solvent; preferably, step (2) further comprises: dissolving the first intermediate and dodecyl dimethyl tertiary amine in the second solvent; and carrying out reduced pressure distillation on a product obtained by the quaternization reaction to remove the second solvent to obtain oily liquid, and then recrystallizing the oily liquid to obtain the second intermediate.
The second solvent is not particularly limited in the present invention as long as it can dissolve the first intermediate and the dodecyldimethyl tertiary amine. Preferably, the second solvent is selected from methanol, ethanol, acetone, toluene, preferably ethanol.
In some embodiments of the present invention, to ensure sufficient reaction between the first intermediate and the dodecyl dimethyl tertiary amine, the mass ratio of the first intermediate to the dodecyl dimethyl tertiary amine is 1:1 to 1:5, preferably 1:1.5 to 1:4, and more preferably 1:1.5 to 1: 2.5.
In some embodiments of the present invention, preferably, the oily liquid is recrystallized using an ethanol/acetone mixed solvent; the mass ratio of the ethanol to the acetone in the ethanol/acetone mixed solvent is 1:1.5-1:3, preferably 1:1.5-1:2.5, and more preferably 1:1.5-1:2.
In some embodiments of the invention, the sulfonation reaction is carried out in the presence of tetrahydrofuran; preferably, step (3) further comprises: dissolving the second intermediate, sultone and MH in tetrahydrofuran, refluxing, mixing the solution obtained after refluxing with ethanol, evaporating the tetrahydrofuran and ethanol solvent under reduced pressure to obtain oily liquid, and recrystallizing the oily liquid to obtain the surfactant.
In some embodiments of the invention, the moisture content in the tetrahydrofuran should be less than 1 wt%. The tetrahydrofuran may be purified by removal of water using methods conventional in the art. Preferably, the process of water removal and purification comprises the following steps: adding anhydrous CaCl into tetrahydrofuran2And filtering to obtain a reaction solvent I, adding a sodium strip into the reaction solvent I, refluxing, and adding benzophenone, wherein if the solution turns blue, the water content in the tetrahydrofuran meets the requirement, otherwise, the tetrahydrofuran is not completely dewatered.
In some embodiments of the present invention, the mass ratio of tetrahydrofuran to anhydrous calcium chloride is 20:1 to 50:1, preferably 20:1 to 40:1, and more preferably 25:1 to 30:1, in order to more completely and thoroughly remove water from tetrahydrofuran. The anhydrous CaCl2And the mass ratio of the sodium strips is 5:1-1:1, preferably 4:1-1:1, and more preferably 3:1-2: 1.
In some embodiments of the invention, benzophenone is used as an indicator to show whether the water removal of tetrahydrofuran is complete. Therefore, the amount of benzophenone used in the present invention is not particularly limited, and is preferably 0.5 to 1.5g, preferably 0.5 to 1.2g, and more preferably 0.5 to 1g, based on 300g of tetrahydrofuran.
In some embodiments of the present invention, preferably, the sultone is selected from propane sultone and/or butane sultone.
In some embodiments of the invention, to ensure that the hydroxyl groups in the second intermediate are fully substituted, the mass ratio of the second intermediate to sultone is from 1:1 to 4:1, preferably from 1:1 to 3:1, more preferably from 1.5:1 to 3: 1. The mass ratio of the second intermediate to MH is 15:1 to 5:1, preferably 10:1 to 5:1, more preferably 10:1 to 6: 1.
In some embodiments of the invention, ethanol is added to remove MH from the solution after reflux. The amount of ethanol used in the present invention is not particularly limited as long as the excess MH in the solution after the reflux can be completely removed. Preferably, the mass ratio of ethanol to MH is 100: 3.
In the present invention, M in MH can be selected to correspond to M in formula I1And M2. Preferably corresponds to M1And M2The same is true.
In some embodiments of the present invention, preferably, the oily liquid is recrystallized from n-hexane.
In a third aspect, the present invention provides a surfactant obtained by the method of the second aspect.
The fourth aspect of the invention provides a preparation method of a microemulsion plugging agent for water-based drilling fluid, which comprises the following steps: mixing an oil phase, brine, a first surfactant, a second surfactant and a cosurfactant to obtain the microemulsion plugging agent; wherein the first surfactant is the surfactant according to the first aspect; the aqueous phase activity of the brine is no greater than 0.85.
The inventor of the present invention found in research that by adding the first surfactant during the preparation of the microemulsion, the prepared microemulsion can be made more stable, and the microemulsion can be formed more easily from high-concentration brine. Moreover, because high-concentration brine is selected in the preparation process of the microemulsion, the prepared microemulsion has better inhibition performance.
In the invention, the formation principle of the microemulsion plugging agent is as follows: in the presence of the surfactant, the oil-water interfacial tension can be greatly reduced, so that a common emulsion is formed, but the microemulsion is not enough to form, and the addition of the cosurfactant can form a mixed adsorption film with surfactant molecules at the oil-water interface. With the further addition of the cosurfactant, the oil-water interfacial tension is reduced to zero or even negative value at a certain moment, and then the system generates more emulsion particles to enlarge the oil-water interfacial area to offset the negative value of the interfacial tension, so that emulsion droplets become very small, and then the microemulsion is formed. If the emulsion droplets coalesce, the interfacial tension returns to a negative value, which in turn causes the emulsion droplets to disperse into finer microemulsion droplets.
In some embodiments of the invention, the second surfactant is selected from one or more of cocamidopropyl hydroxysultaine, bromohexadecyl trimethylamine, perfluoroalkyl polyether phosphate, tween 80 and span 80, preferably span 80.
In some embodiments of the present invention, preferably, the co-surfactant is selected from one of n-pentanol, n-propanol, n-hexanol, n-heptanol, 1, 3-propanediol, n-butanol and polyethylene glycol, preferably one or more of n-pentanol, n-butanol, n-hexanol and n-heptanol.
In some embodiments of the invention, preferably, the oil phase is selected from 3#White oil, 5#White oil, 0#Diesel oil, 5#One of diesel oil, n-octane and n-decane, preferably 3#White oil, 5#White oil, 0#Diesel oil and 5#One kind of diesel oil.
In some embodiments of the present invention, preferably, the brine is selected from one or more of sodium chloride brine, potassium chloride brine, calcium chloride brine, potassium formate brine and sodium formate brine, preferably one of sodium chloride and potassium chloride.
It should be noted that the microemulsion in the prior art generally adopts fresh water or low-concentration brine, and the microemulsion is difficult to form under the high-concentration brine. The invention adopts high-concentration brine to prepare the microemulsion plugging agent for the water-based drilling fluid, and the prepared microemulsion is used in the drilling fluid, and the drilling fluid has strong inhibitive performance.
In some embodiments of the invention, the brine has a water activity of no greater than 0.85. The water activity of the brine may be measured using a water activity meter conventional in the art, for example, a portable water activity meter available from Novasina, switzerland under the model LabSwift-aw.
In some embodiments of the present invention, since the water activity of the brine is directly related to the concentration, the water activity of the brine is not greater than 0.85 when the concentration of the brine satisfies the following condition;
the sodium chloride brine concentration is selected from 10-30 wt%, preferably 15-27 wt%, more preferably 18-24 wt%;
the concentration of the potassium chloride salt in water is selected from 20-40 wt%, preferably 20-35 wt%, more preferably 25-30 wt%;
the calcium chloride salt water concentration is selected from 25-40 wt%, preferably 30-38 wt%, more preferably 30-35 wt%;
the concentration of the potassium formate brine is selected from 25 to 40 wt%, preferably 30 to 38 wt%, more preferably 30 to 35 wt%;
the concentration of the sodium formate brine is selected from 25-40 wt%, preferably 25-35 wt%, more preferably 30-35 wt%.
In some embodiments of the invention, the mass ratio of the first surfactant, second surfactant, co-surfactant, oil phase and brine is from 8-20:1-6:2-4:15-25: 15-25. When the content range is satisfied, the plugging performance and the inhibiting performance of the prepared microemulsion plugging agent can be improved.
In a fifth aspect, the invention provides a microemulsion plugging agent for water-based drilling fluid prepared by the method in the third aspect. The average grain diameter of the microemulsion plugging agent is 10-60 nm. The microemulsion plugging agent for the water-based drilling fluid provided by the invention has a good well wall stabilizing effect, and realizes the unification of strong inhibition and strong plugging performances.
In a sixth aspect, the invention provides a water-based drilling fluid, which comprises the microemulsion plugging agent for the water-based drilling fluid in the fourth aspect. The microemulsion plugging agent provided by the invention is applied to water-based drilling fluid, and the prepared water-based drilling fluid has strong plugging property and inhibition property.
In some embodiments of the invention, the microemulsion plugging agent is present in an amount of 0.5 to 5 wt%, preferably 0.5 to 3 wt%, based on the total amount of the water-based drilling fluid.
According to the invention, when the microemulsions with different concentrations are added into the drilling fluid, the drilling fluid is diluted to form the nano emulsion, and the particle diameters of nano emulsion droplets diluted by the microemulsions with different concentrations are different, so that micro-nano cracks with different sizes can be blocked.
In some embodiments of the invention, the water-based drilling fluid may also contain bentonite clay, conventional treating agents, flow pattern modifiers, and weighting materials. The types and amounts of the bentonite, the conventional treating agent, the flow pattern modifier and the weighting material can be selected conventionally in the field, and the invention is not limited herein.
The present invention will be described in detail below by way of examples. In the following examples and comparative examples:
dimethylamine hydrochloride, diethylamine hydrochloride, and dipropylamine hydrochloride were purchased from shanghai yuhao fine chemicals ltd;
dodecyl dimethyl tertiary amine, propane sultone and butane sultone were purchased from national pharmaceutical group chemical agents, ltd.
Example 1
Preparation of the surfactant:
(1) dissolving 4.1g of dimethylamine hydrochloride in 40g of ethanol, dissolving 10.18g of epichlorohydrin in 12g of ethanol, slowly adding the epichlorohydrin solution into the dimethylamine hydrochloride solution, reacting at the temperature of 50 ℃ for 48 hours, stopping reaction, and evaporating the solvent under reduced pressure to obtain colorless viscous liquid, namely a first intermediate;
(2) dissolving 10g of the first intermediate in 85g of ethanol, slowly adding 20g of dodecyl dimethyl tertiary amine, reacting for 48 hours at the temperature of 60 ℃, stopping the reaction, evaporating the solvent under reduced pressure to obtain light yellow oily liquid, recrystallizing with 40g of ethanol/acetone mixed solvent, and standing for 5 hours at the temperature of 4 ℃ to obtain white powdery solid, namely a second intermediate;
(3) 2g of the second intermediate obtained in step (2) are dissolved in 200g of tetrahydrofuran (water content less than 1% by weight) and N is introduced2Adding 0.3g of NaH, then adding 1g of propane sultone, carrying out reflux reaction for 48h, then adding 10g of ethanol, when no bubbles are generated, carrying out reduced pressure evaporation to remove the solvent (tetrahydrofuran and ethanol) to obtain a light yellow oily liquid, and recrystallizing with n-hexane for 4h at 3 ℃ to obtain a white solid, namely the target product surfactant, which is marked as DMS-1.
Preparing a microemulsion plugging agent for water-based drilling fluid:
10g of 3 are initially introduced at 25 DEG#Mixing white oil, 10g of 21% sodium chloride saline, 6.88g of DMS-1 and 1.12g of span 80, and shaking up; then slowly dropwise adding 1.5g of n-butanol into the solution; after gentle shaking, the mixture was allowed to stand for 24h to form a microemulsion, which was designated as CDMS-1.
Example 2
Preparation of the surfactant:
a surfactant was prepared as in example 1 except that in step (1), "dimethylamine hydrochloride" was modified to "diethylamine hydrochloride" and the amount of amine hydrochloride added was modified from "4.1 g" to "5.5 g", and the surfactant thus prepared was designated DMS-2.
Preparing a microemulsion plugging agent for water-based drilling fluid:
10g of 5 are initially introduced at 25 DEG#Mixing white oil, 10g of 25% potassium chloride brine, 6.88g of DMS-2 and 1.12g of span 80, and shaking up; then 1.5g of n-pentanol was slowly added dropwise thereto; after gentle shaking, the mixture was allowed to stand for 24h to form a microemulsion, which was designated as CDMS-2.
Example 3
Preparation of the surfactant:
a surfactant was prepared as in example 1, except that in step (1), "dimethylamine hydrochloride" was modified to "dipropylamine hydrochloride" and the amount of amine hydrochloride added was modified from "4.1 g" to "6.9 g", and the surfactant thus obtained was designated DMS-3.
Preparing a microemulsion plugging agent for water-based drilling fluid:
10g of 0 are added at 25 DEG C#Diesel oil, 10g of 24% sodium chloride brine, 5.76g of DMS-3 and 2.24g of span 80 are mixed and shaken up; then, 1.5g of n-hexanol was slowly added dropwise thereto; after gentle shaking, the mixture was allowed to stand for 24h to form a microemulsion, which was designated as CDMS-3.
Example 4
Preparation of the surfactant:
a surfactant was prepared as in example 1 except that in step (3), "propane sultone" was modified to "butane sultone" and the amount of sultone added was modified from "1 g" to "1.1 g", and the resulting surfactant was designated DMS-4.
Preparing a microemulsion plugging agent for water-based drilling fluid:
10g of 5 are initially introduced at 25 DEG#Diesel oil, 10g of 28% potassium chloride saline, 5.76g of DMS-4 and 2.24g of span 80 are mixed and shaken up; then 1.5g of n-heptanol was slowly added dropwise thereto; after gentle shaking, the mixture was allowed to stand for 24h to form a microemulsion, which was designated as CDMS-4.
Example 5
Preparing a microemulsion plugging agent for water-based drilling fluid:
10g3 at 25 DEG C#Mixing white oil, 10g of 21% sodium chloride saline, 5.76g of DMS-4 and 2.24g of span 80, and shaking up; then slowly dropwise adding 1.5g of n-butanol into the solution; after gentle shaking, the mixture was allowed to stand for 24h to form a microemulsion, which was designated as CDMS-5.
Test example 1
The surface tensions of the surfactants prepared in examples 1-4 at various concentrations at room temperature were measured using a DCAT21 meter/interfacial tension meter and the results are shown in table 1.
TABLE 1
From the results in table 1, it can be seen that the surface tension of the solution gradually decreases with the increase of the mass concentration of the surfactant, which indicates that the surfactant provided by the present invention can effectively reduce the surface tension of the solution, and when the mass concentration of the surfactant solution is 0.5%, the surface tension of the solution is about 30mN/m, and the effect of reducing the surface tension is significant.
Test example 2
The microemulsion plugging agents for water-based drilling fluids prepared in examples 1 to 5 were tested for their emulsifying and stabilizing properties.
Testing of emulsifying Properties
The volume average particle size of the microemulsion prepared in each of examples 1 to 5 was measured by a Zetasizer Nano S90 Malvern nanosizer analyzer, and the measurement parameters were as follows: general mode (Default); the refractive index of the particles was 1.520; the refractive index of the dispersant is 1.330; rotation speed of the pump: 2050 r/min. The average was taken 3 times per sample. The test results are shown in table 2.
Stability determination
20g of the microemulsion prepared in the examples 1 to 5 are respectively taken to be put into a centrifuge tube, 7000rpm of a high-speed centrifuge is adopted for centrifugation for 10min, and the layering condition of the emulsion is observed. The test results are shown in table 2.
TABLE 2
| CDMS-1 | CDMS-2 | CDMS-3 | CDMS-4 | CDMS-5 | |
| Particle size (nm) | 22.3 | 31.2 | 28.5 | 30.4 | 38.8 |
| Stability of | Not delaminating | Not delaminating | Not delaminating | Not delaminating | Not delaminating |
The data in table 2 show that the particle size of the microemulsion prepared by the invention is less than 50nm, which indicates that the surfactant prepared by the invention has very good emulsifying property, and the centrifugal stability measurement result further proves that the microemulsion prepared by the invention has higher stability.
Test example 3
The clay-free phase water-based drilling fluid is prepared using methods conventional in the art. Based on the total amount of the drilling fluid, the formula of the clay-free water-based drilling fluid is as follows: 400mL of water +0.2 wt% of NaOH +0.3 wt% of PAC-HV +0.3 wt% of XCD +1 wt% of polyamine SDJA-1+3 wt% of ultrafine calcium carbonate (ASP-1250) +3 wt% of ASR-1+100g of barite. Preparing the water-based drilling fluid according to the adding sequence in the formula, wherein the specific operation process comprises the following steps: the treatment agent was added while homogenizing at 10000rpm using a high speed homogenizer. The interval between each treatment agent is 10min, and after all the treatment agents are added, the mixture is continuously stirred for 20min by using a high-speed homogenizer at 10000 rpm. The prepared clay-free water-based drilling fluid is recorded as a basic formula.
3 wt% of the microemulsion plugging agents CDMS-1, CDMS-2, CDMS-3, CDMS-4 and CDMS-5 for water-based drilling fluids prepared in examples 1 to 5 were added to the base formulation, and the rheological parameters and the fluid loss of the drilling fluid before and after hot rolling for 16 hours at 90 ℃ were measured, and the results are shown in Table 3.
Wherein the rheological parameters are tested by a six-speed viscometer model ZNN-D6, a Brookfield viscometer, and comprise apparent viscosity AV, plastic viscosity PV and dynamic shear YP.
And the filtration loss is tested by a ZNS-2 type medium pressure filtration loss instrument.
TABLE 3
The test results in Table 3 show that the rheological property of the drilling fluid is improved by adding the microemulsion plugging agent for water-based drilling fluid provided by the invention into the basic formulaSmall variation of the parameters, FLAPIThe medium-pressure filtration vector is reduced, and the rheological parameters before and after hot rolling and the API filtration loss homogeneous phase are not large, which shows that the drilling fluid system added with the microemulsion plugging agent for water-based drilling fluid has good temperature resistance, the formed mud cake has good quality, and can effectively plug and reduce the penetration of filtrate.
The plugging effect of each drilling fluid was evaluated using a high temperature high pressure osmometer (PPT) at 120 ℃/3.5MPa, with the test results shown in table 4.
TABLE 4
The test results in Table 4 show that the HTHP/FL of the drilling fluid is smaller after the microemulsion plugging agent for water-based drilling fluid is added into a basic formula, and the plugging effect of the water-based drilling fluid provided by the invention is better.
Test example 4
The inhibition performance of the microemulsion plugging agent for the water-based drilling fluid is evaluated through 2 indexes of shale expansion rate and shale recovery rate.
Shale expansion experiment:
the standard calcareous soil 10g is placed into a self-made mold and is pressed for 5min under the pressure of 10MPa of a press machine, so that an artificial core is obtained, and the linear expansion rates of the artificial core in clear water, a drilling fluid basic formula and a drilling fluid containing the microemulsion plugging agent are measured by an intelligent shale expansion instrument, wherein the results are shown in Table 5.
TABLE 5
The results in table 5 show that the swelling rate of the artificial rock core in clear water is 10.48%, the swelling rate in the water-based drilling fluid base slurry is 1.64%, and the swelling rate is only 1.22% -1.45% after the microemulsion plugging agent is added into the water-based drilling fluid base slurry, which indicates that the microemulsion provided by the invention has good inhibition performance.
Shale rolling dispersion experiment:
50g of shale of the sand river street group of the Shengli oil field with the particle size of 5-10 meshes is taken and respectively put into 350mL of clear water, a drilling fluid basic formula and a water-based drilling fluid containing a microemulsion plugging agent, the clear water, the drilling fluid basic formula and the water-based drilling fluid are hot rolled for 16h at 100 ℃, then the clear water is sieved by a standard sieve with 40 meshes, the residue is dried at 105 ℃, and then the rock debris recovery rate is measured, and the results are shown in Table 6.
TABLE 6
The results in Table 6 show that the rock debris recovery rate reaches more than 90% after 3 wt% of the microemulsion plugging agent for water-based drilling fluid is added, which indicates that the microemulsion plugging agent for water-based drilling fluid has strong shale hydration dispersion inhibiting performance.
In conclusion, the microemulsion plugging agent for the water-based drilling fluid provided by the invention has the average particle size of 10-60nm and good stability. The microemulsion plugging agent provided by the invention is applied to water-based drilling fluid, and the prepared water-based drilling fluid has strong plugging property and inhibition property.
The preferred embodiments of the present invention have been described above in detail, but the present invention is not limited thereto. Within the scope of the technical idea of the invention, many simple modifications can be made to the technical solution of the invention, including combinations of various technical features in any other suitable way, and these simple modifications and combinations should also be regarded as the disclosure of the invention, and all fall within the scope of the invention.
Claims (15)
1. The surfactant is characterized in that the structure of the surfactant is shown as a structural formula I
Wherein R is1is-CH3、-CH2CH3or-CH2CH2CH3，R2is-CH3、-CH2CH3or-CH2CH2CH3，R3Is- (CH)2)3-or- (CH)2)4-，R4Is- (CH)2)3-or- (CH)2)4-，M1Is Li, Na or K, M2Is Li, Na or K.
2. A preparation method of a surfactant is characterized by comprising the following steps:
(1) carrying out ring-opening reaction on amine hydrochloride shown in a formula II and epoxy chloropropane to obtain a first intermediate;
(2) Carrying out quaternization reaction on the first intermediate and dodecyl dimethyl tertiary amine to obtain a second intermediate;
(3) carrying out sulfonation reaction on the second intermediate, sultone shown in a formula III and a compound shown in a general formula MH to obtain the surfactant,
3. The process of claim 2, wherein the ring-opening reaction is carried out in the presence of a first solvent; preferably, step (1) further comprises: dissolving amine hydrochloride and epichlorohydrin in the first solvent; and carrying out reduced pressure distillation on the product solution obtained by the ring-opening reaction to remove the first solvent, so as to obtain the first intermediate.
4. The process of claim 2 or 3, wherein the amine hydrochloride is selected from one or more of dimethylamine hydrochloride, diethylamine hydrochloride, and dipropylamine hydrochloride;
preferably, the mass ratio of the amine hydrochloride to the epichlorohydrin is 1:1 to 1:5, preferably 1:1 to 1:4, and more preferably 1:1.3 to 1: 3.
5. The method of claim 2, wherein the quaternization reaction is carried out in the presence of a second solvent; preferably, step (2) further comprises: dissolving the first intermediate and dodecyl dimethyl tertiary amine in the second solvent; and carrying out reduced pressure distillation on a product obtained by the quaternization reaction to remove the second solvent to obtain oily liquid, and then recrystallizing the oily liquid to obtain the second intermediate.
6. The process according to claim 2 or 5, wherein the mass ratio of the first intermediate to the dodecyldimethyl tertiary amine is from 1:1 to 1:5, preferably from 1:1.5 to 1:4, more preferably from 1:1.5 to 1: 2.5.
7. The process according to claim 2, wherein the sulfonation reaction is carried out in the presence of tetrahydrofuran; preferably, step (3) further comprises: dissolving the second intermediate, sultone and MH in tetrahydrofuran, refluxing, mixing the solution obtained after refluxing with ethanol, evaporating the tetrahydrofuran and ethanol solvent under reduced pressure to obtain oily liquid, and recrystallizing the oily liquid to obtain the surfactant.
8. The process according to claim 2 or 7, wherein the sultone is selected from propane sultone and/or butane sultone;
preferably, the mass ratio of the second intermediate to the sultone is 1:1 to 4:1, preferably 1:1 to 3:1, more preferably 1.5:1 to 3: 1.
9. A surfactant obtainable by the process of any one of claims 2 to 8.
10. The preparation method of the microemulsion plugging agent for the water-based drilling fluid is characterized by comprising the following steps: mixing an oil phase, brine, a first surfactant, a second surfactant and a cosurfactant to obtain the microemulsion plugging agent; wherein the first surfactant is the surfactant of claim 1 or 9; the aqueous phase activity of the brine is no greater than 0.85.
11. A process according to claim 10, wherein the second surfactant is selected from one or more of cocamidopropyl hydroxysultaine, bromohexadecyl trimethylamine, perfluoroalkyl polyether phosphate, tween 80 and span 80, preferably span 80;
preferably, the co-surfactant is selected from one or more of n-pentanol, n-propanol, n-hexanol, n-heptanol, 1, 3-propanediol, n-butanol and polyethylene glycol;
preferably, the oil phase is selected from 3#White oil, 5#White oil, 0#Diesel oil, 5#One of diesel oil, n-octane and n-decane;
preferably, the brine is selected from one or more of sodium chloride brine, potassium chloride brine, calcium chloride brine, potassium formate brine and sodium formate brine.
12. The method of claim 10 or 11, wherein the mass ratio of the first surfactant, second surfactant, co-surfactant, oil phase and brine is 8-20:1-6:2-4:15-25: 15-25.
13. A microemulsion plugging agent for water-based drilling fluids prepared by the method of any one of claims 10 to 12, wherein the average particle size of the microemulsion plugging agent is 10 to 60 nm.
14. A water-based drilling fluid comprising the microemulsion plugging agent for water-based drilling fluid of claim 13.
15. The water-based drilling fluid according to claim 14, wherein the microemulsion plugging agent is present in an amount of 0.5-5 wt%, preferably 0.5-3 wt%, based on the total amount of the water-based drilling fluid.
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| CN115197721A (en) * | 2022-05-16 | 2022-10-18 | 北京格锐普华科技发展有限责任公司 | Oil body liquid seal composition and preparation method thereof |
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| CN115197721A (en) * | 2022-05-16 | 2022-10-18 | 北京格锐普华科技发展有限责任公司 | Oil body liquid seal composition and preparation method thereof |
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Inventor after: Zhong Hanyi Inventor after: Cai Wenming Inventor after: Qiu Zhengsong Inventor after: Gao Wenlong Inventor after: Dong Bingqiang Inventor after: Huang Weian Inventor after: Guan Ying Inventor after: Mou Tingbo Inventor before: Zhong Hanyi Inventor before: Cai Wenming Inventor before: Qiu Zhengsong Inventor before: Dong Bingqiang Inventor before: Huang Weian Inventor before: Guan Ying Inventor before: Mou Tingbo |