CN116333705B - Responsive gel temporary plugging agent applicable to high-temperature oil reservoir as well as preparation method and application thereof - Google Patents
Responsive gel temporary plugging agent applicable to high-temperature oil reservoir as well as preparation method and application thereof Download PDFInfo
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- CN116333705B CN116333705B CN202310226985.9A CN202310226985A CN116333705B CN 116333705 B CN116333705 B CN 116333705B CN 202310226985 A CN202310226985 A CN 202310226985A CN 116333705 B CN116333705 B CN 116333705B
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- Prior art keywords
- temporary plugging
- plugging agent
- gel
- responsive gel
- temperature
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- 238000002360 preparation method Methods 0.000 title claims abstract description 23
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 75
- 239000011259 mixed solution Substances 0.000 claims abstract description 28
- 239000003960 organic solvent Substances 0.000 claims abstract description 24
- 150000001412 amines Chemical class 0.000 claims abstract description 21
- 239000003431 cross linking reagent Substances 0.000 claims abstract description 20
- 229910052751 metal Inorganic materials 0.000 claims abstract description 16
- 239000002184 metal Substances 0.000 claims abstract description 16
- 150000003839 salts Chemical class 0.000 claims abstract description 16
- 238000000034 method Methods 0.000 claims abstract description 14
- 239000003513 alkali Substances 0.000 claims abstract description 8
- 238000002156 mixing Methods 0.000 claims abstract description 8
- 239000000243 solution Substances 0.000 claims description 40
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical group OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 claims description 33
- 238000011065 in-situ storage Methods 0.000 claims description 13
- 150000001299 aldehydes Chemical class 0.000 claims description 11
- 238000005553 drilling Methods 0.000 claims description 9
- IAZDPXIOMUYVGZ-UHFFFAOYSA-N Dimethylsulphoxide Chemical compound CS(C)=O IAZDPXIOMUYVGZ-UHFFFAOYSA-N 0.000 claims description 8
- 239000004721 Polyphenylene oxide Substances 0.000 claims description 8
- 229920000570 polyether Polymers 0.000 claims description 8
- 229930040373 Paraformaldehyde Natural products 0.000 claims description 7
- 229920002873 Polyethylenimine Polymers 0.000 claims description 7
- 229920002866 paraformaldehyde Polymers 0.000 claims description 7
- HUMNYLRZRPPJDN-UHFFFAOYSA-N benzaldehyde Chemical compound O=CC1=CC=CC=C1 HUMNYLRZRPPJDN-UHFFFAOYSA-N 0.000 claims description 6
- SECXISVLQFMRJM-UHFFFAOYSA-N N-Methylpyrrolidone Chemical compound CN1CCCC1=O SECXISVLQFMRJM-UHFFFAOYSA-N 0.000 claims description 5
- ZMXDDKWLCZADIW-UHFFFAOYSA-N N,N-Dimethylformamide Chemical compound CN(C)C=O ZMXDDKWLCZADIW-UHFFFAOYSA-N 0.000 claims description 4
- 229920001661 Chitosan Polymers 0.000 claims description 3
- VTLYFUHAOXGGBS-UHFFFAOYSA-N Fe3+ Chemical compound [Fe+3] VTLYFUHAOXGGBS-UHFFFAOYSA-N 0.000 claims description 3
- 150000001768 cations Chemical class 0.000 claims description 3
- 150000004985 diamines Chemical class 0.000 claims description 3
- 229910001447 ferric ion Inorganic materials 0.000 claims description 3
- 238000004519 manufacturing process Methods 0.000 claims description 3
- 229910021645 metal ion Inorganic materials 0.000 claims description 3
- QNGNSVIICDLXHT-UHFFFAOYSA-N para-ethylbenzaldehyde Natural products CCC1=CC=C(C=O)C=C1 QNGNSVIICDLXHT-UHFFFAOYSA-N 0.000 claims description 3
- QCDWFXQBSFUVSP-UHFFFAOYSA-N 2-phenoxyethanol Chemical compound OCCOC1=CC=CC=C1 QCDWFXQBSFUVSP-UHFFFAOYSA-N 0.000 claims description 2
- 125000003172 aldehyde group Chemical group 0.000 claims description 2
- 125000003277 amino group Chemical group 0.000 claims description 2
- VKYKSIONXSXAKP-UHFFFAOYSA-N hexamethylenetetramine Chemical compound C1N(C2)CN3CN1CN2C3 VKYKSIONXSXAKP-UHFFFAOYSA-N 0.000 claims description 2
- WSFSSNUMVMOOMR-NJFSPNSNSA-N methanone Chemical compound O=[14CH2] WSFSSNUMVMOOMR-NJFSPNSNSA-N 0.000 claims description 2
- 229910001428 transition metal ion Inorganic materials 0.000 claims description 2
- 230000007704 transition Effects 0.000 claims 1
- 239000002994 raw material Substances 0.000 abstract description 11
- 239000002253 acid Substances 0.000 abstract description 10
- 230000008901 benefit Effects 0.000 abstract description 8
- 230000000903 blocking effect Effects 0.000 abstract description 8
- 230000000694 effects Effects 0.000 abstract description 8
- 230000008569 process Effects 0.000 abstract description 8
- 239000000463 material Substances 0.000 abstract description 5
- 238000000605 extraction Methods 0.000 abstract description 4
- 230000007613 environmental effect Effects 0.000 abstract description 3
- 230000020477 pH reduction Effects 0.000 abstract description 3
- 125000002485 formyl group Chemical class [H]C(*)=O 0.000 abstract 1
- 239000000499 gel Substances 0.000 description 111
- 239000007789 gas Substances 0.000 description 17
- 230000000052 comparative effect Effects 0.000 description 13
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 description 12
- 239000003292 glue Substances 0.000 description 9
- 238000011161 development Methods 0.000 description 8
- 238000005516 engineering process Methods 0.000 description 7
- 239000007788 liquid Substances 0.000 description 7
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 description 6
- 150000007529 inorganic bases Chemical class 0.000 description 6
- 229920002401 polyacrylamide Polymers 0.000 description 6
- 229920000642 polymer Polymers 0.000 description 6
- 239000007787 solid Substances 0.000 description 6
- 238000003756 stirring Methods 0.000 description 6
- 239000000126 substance Substances 0.000 description 6
- 238000012360 testing method Methods 0.000 description 6
- 229910017053 inorganic salt Inorganic materials 0.000 description 5
- DZSVIVLGBJKQAP-UHFFFAOYSA-N 1-(2-methyl-5-propan-2-ylcyclohex-2-en-1-yl)propan-1-one Chemical compound CCC(=O)C1CC(C(C)C)CC=C1C DZSVIVLGBJKQAP-UHFFFAOYSA-N 0.000 description 4
- 230000015572 biosynthetic process Effects 0.000 description 4
- 239000002981 blocking agent Substances 0.000 description 4
- 238000004132 cross linking Methods 0.000 description 4
- 239000012530 fluid Substances 0.000 description 4
- 239000004816 latex Substances 0.000 description 4
- 229920000126 latex Polymers 0.000 description 4
- 239000002245 particle Substances 0.000 description 4
- HRPVXLWXLXDGHG-UHFFFAOYSA-N Acrylamide Chemical compound NC(=O)C=C HRPVXLWXLXDGHG-UHFFFAOYSA-N 0.000 description 3
- KWYUFKZDYYNOTN-UHFFFAOYSA-M Potassium hydroxide Chemical compound [OH-].[K+] KWYUFKZDYYNOTN-UHFFFAOYSA-M 0.000 description 3
- 230000007547 defect Effects 0.000 description 3
- 238000002347 injection Methods 0.000 description 3
- 239000007924 injection Substances 0.000 description 3
- 239000000178 monomer Substances 0.000 description 3
- 238000005086 pumping Methods 0.000 description 3
- JIAARYAFYJHUJI-UHFFFAOYSA-L zinc dichloride Chemical compound [Cl-].[Cl-].[Zn+2] JIAARYAFYJHUJI-UHFFFAOYSA-L 0.000 description 3
- SMZOUWXMTYCWNB-UHFFFAOYSA-N 2-(2-methoxy-5-methylphenyl)ethanamine Chemical compound COC1=CC=C(C)C=C1CCN SMZOUWXMTYCWNB-UHFFFAOYSA-N 0.000 description 2
- NIXOWILDQLNWCW-UHFFFAOYSA-N 2-Propenoic acid Natural products OC(=O)C=C NIXOWILDQLNWCW-UHFFFAOYSA-N 0.000 description 2
- FPFSGDXIBUDDKZ-UHFFFAOYSA-N 3-decyl-2-hydroxycyclopent-2-en-1-one Chemical compound CCCCCCCCCCC1=C(O)C(=O)CC1 FPFSGDXIBUDDKZ-UHFFFAOYSA-N 0.000 description 2
- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 description 2
- 229910021578 Iron(III) chloride Inorganic materials 0.000 description 2
- 239000011837 N,N-methylenebisacrylamide Substances 0.000 description 2
- 230000009471 action Effects 0.000 description 2
- VSCWAEJMTAWNJL-UHFFFAOYSA-K aluminium trichloride Chemical compound Cl[Al](Cl)Cl VSCWAEJMTAWNJL-UHFFFAOYSA-K 0.000 description 2
- 150000007854 aminals Chemical class 0.000 description 2
- 238000009933 burial Methods 0.000 description 2
- YKYOUMDCQGMQQO-UHFFFAOYSA-L cadmium dichloride Chemical compound Cl[Cd]Cl YKYOUMDCQGMQQO-UHFFFAOYSA-L 0.000 description 2
- 239000001110 calcium chloride Substances 0.000 description 2
- 229910001628 calcium chloride Inorganic materials 0.000 description 2
- 230000015556 catabolic process Effects 0.000 description 2
- 238000006555 catalytic reaction Methods 0.000 description 2
- 238000010276 construction Methods 0.000 description 2
- 230000006378 damage Effects 0.000 description 2
- 230000007423 decrease Effects 0.000 description 2
- 238000006731 degradation reaction Methods 0.000 description 2
- 238000004090 dissolution Methods 0.000 description 2
- 239000000835 fiber Substances 0.000 description 2
- LEQAOMBKQFMDFZ-UHFFFAOYSA-N glyoxal Chemical compound O=CC=O LEQAOMBKQFMDFZ-UHFFFAOYSA-N 0.000 description 2
- 239000003999 initiator Substances 0.000 description 2
- RBTARNINKXHZNM-UHFFFAOYSA-K iron trichloride Chemical compound Cl[Fe](Cl)Cl RBTARNINKXHZNM-UHFFFAOYSA-K 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- ZIUHHBKFKCYYJD-UHFFFAOYSA-N n,n'-methylenebisacrylamide Chemical compound C=CC(=O)NCNC(=O)C=C ZIUHHBKFKCYYJD-UHFFFAOYSA-N 0.000 description 2
- 238000011084 recovery Methods 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- 230000004044 response Effects 0.000 description 2
- 230000007281 self degradation Effects 0.000 description 2
- 150000003384 small molecules Chemical class 0.000 description 2
- 239000002904 solvent Substances 0.000 description 2
- 230000000087 stabilizing effect Effects 0.000 description 2
- 238000003786 synthesis reaction Methods 0.000 description 2
- UMGDCJDMYOKAJW-UHFFFAOYSA-N thiourea Chemical compound NC(N)=S UMGDCJDMYOKAJW-UHFFFAOYSA-N 0.000 description 2
- 239000011592 zinc chloride Substances 0.000 description 2
- JYEUMXHLPRZUAT-UHFFFAOYSA-N 1,2,3-triazine Chemical compound C1=CN=NN=C1 JYEUMXHLPRZUAT-UHFFFAOYSA-N 0.000 description 1
- XMNIXWIUMCBBBL-UHFFFAOYSA-N 2-(2-phenylpropan-2-ylperoxy)propan-2-ylbenzene Chemical compound C=1C=CC=CC=1C(C)(C)OOC(C)(C)C1=CC=CC=C1 XMNIXWIUMCBBBL-UHFFFAOYSA-N 0.000 description 1
- VHUUQVKOLVNVRT-UHFFFAOYSA-N Ammonium hydroxide Chemical compound [NH4+].[OH-] VHUUQVKOLVNVRT-UHFFFAOYSA-N 0.000 description 1
- ZNZYKNKBJPZETN-WELNAUFTSA-N Dialdehyde 11678 Chemical compound N1C2=CC=CC=C2C2=C1[C@H](C[C@H](/C(=C/O)C(=O)OC)[C@@H](C=C)C=O)NCC2 ZNZYKNKBJPZETN-WELNAUFTSA-N 0.000 description 1
- XSQUKJJJFZCRTK-UHFFFAOYSA-N Urea Natural products NC(N)=O XSQUKJJJFZCRTK-UHFFFAOYSA-N 0.000 description 1
- 229920001938 Vegetable gum Polymers 0.000 description 1
- 238000005910 aminocarbonylation reaction Methods 0.000 description 1
- 235000011114 ammonium hydroxide Nutrition 0.000 description 1
- BFNBIHQBYMNNAN-UHFFFAOYSA-N ammonium sulfate Chemical compound N.N.OS(O)(=O)=O BFNBIHQBYMNNAN-UHFFFAOYSA-N 0.000 description 1
- 229910052921 ammonium sulfate Inorganic materials 0.000 description 1
- 239000001166 ammonium sulphate Substances 0.000 description 1
- 235000011130 ammonium sulphate Nutrition 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000009835 boiling Methods 0.000 description 1
- 239000011575 calcium Substances 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 229910001430 chromium ion Inorganic materials 0.000 description 1
- 230000000536 complexating effect Effects 0.000 description 1
- 238000010668 complexation reaction Methods 0.000 description 1
- 239000002131 composite material Substances 0.000 description 1
- 230000006835 compression Effects 0.000 description 1
- 238000007906 compression Methods 0.000 description 1
- 238000001816 cooling Methods 0.000 description 1
- ORTQZVOHEJQUHG-UHFFFAOYSA-L copper(II) chloride Chemical compound Cl[Cu]Cl ORTQZVOHEJQUHG-UHFFFAOYSA-L 0.000 description 1
- 230000006196 deacetylation Effects 0.000 description 1
- 238000003381 deacetylation reaction Methods 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- 239000006185 dispersion Substances 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 239000012153 distilled water Substances 0.000 description 1
- 238000011156 evaluation Methods 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 230000002349 favourable effect Effects 0.000 description 1
- 229960002089 ferrous chloride Drugs 0.000 description 1
- 229940015043 glyoxal Drugs 0.000 description 1
- 238000010438 heat treatment Methods 0.000 description 1
- 230000007062 hydrolysis Effects 0.000 description 1
- 238000006460 hydrolysis reaction Methods 0.000 description 1
- 230000002209 hydrophobic effect Effects 0.000 description 1
- 230000015784 hyperosmotic salinity response Effects 0.000 description 1
- 230000000977 initiatory effect Effects 0.000 description 1
- NMCUIPGRVMDVDB-UHFFFAOYSA-L iron dichloride Chemical compound Cl[Fe]Cl NMCUIPGRVMDVDB-UHFFFAOYSA-L 0.000 description 1
- 239000003446 ligand Substances 0.000 description 1
- 230000007774 longterm Effects 0.000 description 1
- 229920002521 macromolecule Polymers 0.000 description 1
- 238000010907 mechanical stirring Methods 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 230000001590 oxidative effect Effects 0.000 description 1
- 125000004430 oxygen atom Chemical group O* 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 239000003209 petroleum derivative Substances 0.000 description 1
- 238000006116 polymerization reaction Methods 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- USHAGKDGDHPEEY-UHFFFAOYSA-L potassium persulfate Chemical compound [K+].[K+].[O-]S(=O)(=O)OOS([O-])(=O)=O USHAGKDGDHPEEY-UHFFFAOYSA-L 0.000 description 1
- 238000003908 quality control method Methods 0.000 description 1
- 238000012827 research and development Methods 0.000 description 1
- 230000004043 responsiveness Effects 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 238000012216 screening Methods 0.000 description 1
- 239000007858 starting material Substances 0.000 description 1
- IEXRMSFAVATTJX-UHFFFAOYSA-N tetrachlorogermane Chemical compound Cl[Ge](Cl)(Cl)Cl IEXRMSFAVATTJX-UHFFFAOYSA-N 0.000 description 1
- 239000002562 thickening agent Substances 0.000 description 1
- 229910052723 transition metal Inorganic materials 0.000 description 1
- -1 transition metal cation Chemical class 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Chemical compound O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
- 229920001285 xanthan gum Polymers 0.000 description 1
- 239000000230 xanthan gum Substances 0.000 description 1
- 229940082509 xanthan gum Drugs 0.000 description 1
- 235000010493 xanthan gum Nutrition 0.000 description 1
- 235000005074 zinc chloride Nutrition 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/516—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls characterised by their form or by the form of their components, e.g. encapsulated material
-
- 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
- C09K8/5045—Compositions based on water or polar solvents containing inorganic compounds
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—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
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/5083—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained by reactions only involving carbon-to-carbon unsaturated bonds
-
- 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
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/5086—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds
-
- 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
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/512—Compositions based on water or polar solvents containing organic compounds macromolecular compounds containing cross-linking agents
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
- E21B33/138—Plastering the borehole wall; Injecting into the formation
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Chemical & Material Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Organic Chemistry (AREA)
- Materials Engineering (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Fluid Mechanics (AREA)
- Geochemistry & Mineralogy (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Inorganic Chemistry (AREA)
- Processes Of Treating Macromolecular Substances (AREA)
- Compositions Of Macromolecular Compounds (AREA)
Abstract
The invention discloses a responsive gel temporary plugging agent suitable for a high-temperature oil reservoir, and a preparation method and application thereof. The preparation method comprises the following steps: dissolving an aldehyde cross-linking agent into a first organic solvent containing inorganic alkali to obtain a first mixed solution; dissolving metal salt and high molecular organic amine into a second organic solvent to obtain a second mixed solution; and uniformly mixing the first mixed solution and the second mixed solution to obtain the responsive gel temporary plugging agent. The responsive gel temporary plugging agent suitable for the high-temperature oil reservoir has the remarkable advantages of simple preparation, low-cost raw materials, environmental friendliness and the like; the material can automatically gel at the reservoir temperature, has excellent temperature resistance, can effectively simplify the gel breaking process by using acid liquor in the processes of acidification, acid pressure and the like, has high blocking removal rate, and can further strengthen oil extraction by decomposing gel into amphiphilic products with surface activity by the acid liquor.
Description
Technical Field
The invention relates to the technical field of oil and gas field application chemistry, in particular to a responsive gel temporary plugging agent suitable for a high-temperature oil reservoir, and a preparation method and application thereof.
Background
According to the dynamic evaluation result of national oil gas resources in 2015, the oil gas resources in deep and ultra-deep layers reach 671 hundred million tons of oil gas equivalent, and account for 34% of the total oil gas resources. The exploration and development of deep oil and gas resources are widely focused, and the newly-increased reserves of global deep oil and gas are in a remarkable growing trend. Taking a Tarim basin as an example, oil and gas resources with burial depths of 6,000 to 10,000 meters account for 73% of the total amount, and the development potential is huge. Therefore, the method has very important significance for expanding reserves and stabilizing yield of new and old oil and gas fields. The development and research of deep and ultra-deep oil and gas resources in China have been advanced, but the efficient exploration and benefit development of the resources face a plurality of challenges due to the characteristics of deep burial, ultra-high temperature and ultra-high pressure.
Multi-branch well technology is a new type of drilling technology developed on the basis of conventional horizontal wells and branch wells. The technology can drill two or more branch wellbores (secondary wellbores) from the fundus part of a main well, drill a tertiary wellbore from the secondary wellbores, improve the utilization rate of the well through the continuously separated secondary wellbores, obtain larger oil drainage area and oil drainage capacity, reduce the development cost of oil gas, and is one of main process technologies for the development of oil and gas fields in the 21 st century. The temporary plugging agent is an important material in the development engineering of the multi-branch horizontal well, when the well bores of the same class are developed, the well bores which are drilled first are required to be plugged, the well bores are turned to the well bores of the same class, and after the well bores of the same class are completed, the well bores are completely plugged and communicated to the well bores of the upper class. The temporary plugging agent can effectively prevent drilling fluid from leaking into a non-construction well, reduce drilling cost and effectively protect a reservoir from being polluted.
The temporary plugging agent mainly comprises fibers, solid particles, gels and the like. The temporary plugging agents can be divided into prefabricated (fiber type, solid particle type and prefabricated gel type) and in-situ (in-situ gel type) temporary plugging agents according to whether chemical changes occur before and after plugging. The prefabricated temporary plugging agent is mainly solid and has the advantages of high plugging strength, good temperature resistance and the like. During operation, the particle size of the plugging agent needs to meet the principle of 1/2-2/3, the continuous real-time screening of the particle size of the material to match cracks can seriously reduce the working efficiency, and the high friction between the solid and the well wall needs higher pumping pressure to increase potential safety hazards. The in-situ gel temporary plugging agent is in a liquid state, has small friction with the well wall and is easy to pump. After entering the stratum, the temporary plugging agent penetrates into the well and the crack under the action of pressure difference and permeation, and after reaching the crosslinking temperature, the temporary plugging agent forms glue and plugs the well and the crack. Therefore, compared with the prefabricated type, the in-situ gel temporary plugging agent has excellent stratum adaptability and compatibility. In-situ gel temporary plugging agents generally mainly comprise two gel breaking modes of self-degradation and gel breaker injection. The degradation time and the plugging removal efficiency of the self-degradation gel breaking are greatly influenced by temperature and are difficult to regulate and control, and reservoir pollution is easily caused when the plugging removal is incomplete. The breaker has the defects of complex process, high use cost and the like. The in-situ gel temporary plugging agent is endowed with excellent responsiveness by introducing the responsive group, so that the gel can change phase along with the environment (pH, temperature, solution dissolution property and the like) and respond to gel breaking, and the purpose of controllable plugging removal can be achieved by combining with acid fracturing modification, production oil extraction, hydraulic fracturing and other yield increasing measures without injecting a gel breaker.
The research and development of the high-temperature-resistant organic temporary plugging agent is one of key technologies for efficiently developing high-temperature (> 120 ℃) oil and gas resources, but few research reports of the high-temperature-resistant in-situ gel temporary plugging agent applicable to high-temperature oil and gas reservoirs exist at present. Li Dan et al prepared a high temperature (120 ℃) resistant temporary plugging agent by crosslinking polyacrylamide (molecular weight is 1200 ten thousand, degree of hydrolysis is less than 5%) with high Wen Ge crosslinking agent G. The plugging agent has the advantages of good salt resistance, high gel forming strength, adjustable stabilizing time and the like under the optimal application condition, the plugging rate of cores with different permeabilities reaches 92.75 percent, but the plugging removal rate is only 83.19 percent, and the plugging agent is easy to decompose after the use temperature exceeds 120 ℃, so that the plugging agent is difficult to be applied to high-temperature oil reservoirs (applied chemical industry, 2011, 40 (12)). Xiong Ying et al adopts a slow-release cross-linking agent obtained by complexing an inorganic salt cross-linking agent with polyhydroxy ligand, and the cross-linking agent is a temporary plugging agent which can resist the high temperature of 120 ℃ after being cross-linked with composite modified vegetable gum, the viscosity after gel formation can reach 30000 mPas, the viscosity after plugging removal by acid solution can be smoothly returned to the row as low as 5 mPas, and the cost is still higher although the raw materials are green and environment-friendly (petroleum and natural gas chemical industry, 2018, 47 (06)). Guo Jintang et al use Acrylamide (AM), acrylic Acid (AA) and a temperature-resistant monomer 2-acrylamide-2-methylpropanesulfonic Acid (AMPS) as main raw materials, N, N-methylenebisacrylamide (BIS) as a cross-linking agent, and can respond to gel blocking at the formation temperature after adding a high-temperature initiator dicumyl peroxide. The temporary plugging agent contains a-SO 3 - group, 3 oxygen atoms in the-SO 3 - group are all of strong electronegativity, and share a negative charge with pi bond, SO that the-SO 3 - group is very stable and is not easy to be influenced by external cations, and the salt tolerance of the temporary plugging agent can be improved by introducing the-SO 3 - group. However, due to the stability of the initiator, the highest initiation temperature (i.e., gel forming temperature) is 125 ℃, and although the cost is slightly reduced, the high-temperature stratum use (university of Tianjin (edition of natural science and engineering technology), 2019, 52 (01)) cannot be promoted. Liu Wei et al, based on an aminocarbonylation reaction, prepared an in situ gel type temporary plugging agent capable of resisting high temperature of 140 ℃ by crosslinking AMPS modified polyacrylamide with polyethyleneimine. The temporary plugging agent has plugging strength of 9MPa and plugging removal rate of 90.00%, and is successful in temporary plugging of a well in a long-term celebration (drilling fluid and completion fluid, 2019, 36 (06)). Meanwhile, the organic temporary plugging agent and the system reported in the patent CN105018050A, CN1047686A, CN104710967A have the defects of low temperature resistance (140 ℃) or incomplete degradation (90.00 percent of plugging removal rate) and the like. In the working, the temporary plugging agent is mostly prepared by crosslinking polyacrylamide by using crosslinking agents such as chromium ions, PEI, BIS and the like, but the application range is limited due to the factors such as environmental harm or high production cost of the crosslinking agents, difficult flowback caused by the fact that gel breaking products generally have no surface interface activity and the like. In addition, the complex preparation process and the complicated construction mode lead to difficult quality control and field application of the product, and prevent benefit development of the high-temperature oil reservoir.
Disclosure of Invention
The invention aims to overcome the technical defects, and provides a responsive gel temporary plugging agent suitable for a high-temperature oil reservoir, and a preparation method and application thereof, and solves the technical problems of poor high-temperature resistance, low plugging removal rate and complex preparation method of the gel temporary plugging agent in the prior art.
In a first aspect, the invention provides a preparation method of a responsive gel temporary plugging agent suitable for a high-temperature oil reservoir, comprising the following steps:
Dissolving an aldehyde cross-linking agent into a first organic solvent containing inorganic alkali to obtain a first mixed solution;
Dissolving metal salt and high molecular organic amine into a second organic solvent to obtain a second mixed solution;
And uniformly mixing the first mixed solution and the second mixed solution to obtain the responsive gel temporary plugging agent.
In a second aspect, the invention provides a responsive gel temporary plugging agent applicable to a high-temperature oil reservoir, which is obtained by the preparation method of the responsive gel temporary plugging agent applicable to the high-temperature oil reservoir.
In a third aspect, the invention provides an application of a responsive gel temporary plugging agent suitable for a high-temperature oil reservoir, and the responsive gel temporary plugging agent suitable for the high-temperature oil reservoir is used as an in-situ temporary plugging agent for oil and gas field drilling and oil recovery processes.
Compared with the prior art, the invention has the beneficial effects that:
The responsive gel temporary plugging agent suitable for the high-temperature oil reservoir (120-160 ℃) has the remarkable advantages of simple preparation, low-cost raw materials, environmental friendliness and the like; the material can automatically gel at the reservoir temperature, has excellent temperature resistance, causes gel responsive gel breaking, can effectively simplify the gel breaking process by using the acid liquid in the processes of acidification, acid fracturing and the like, has high blocking removal rate, and can further enhance oil extraction by decomposing gel into amphiphilic products with surface activity by the acid liquid.
Drawings
Fig. 1 shows the state of the responsive gel temporary plugging agent for high temperature oil reservoir prepared in example 1 according to the present invention at different treatment stages: (a) a gelling solution; (b) a polymer gel; (c) breaking the glue solution;
FIG. 2 is a graph showing the viscosity temperature of the gelling solution prepared in example 1 of the present invention in the range of normal temperature to 100deg.C;
FIG. 3 is a graph of the surface tension of the latex breaking solution and raw material ED-2003 obtained in example 1 of the present invention;
FIG. 4 is a Scanning Electron Microscope (SEM) image of a responsive gel temporary plugging agent prepared in example 1 of the present invention;
FIG. 5 is a stress-strain curve of the responsive gel temporary plugging agent prepared in example 1 and the aminal gel prepared in comparative example 3.
Detailed Description
The present invention will be described in further detail with reference to the drawings and examples, in order to make the objects, technical solutions and advantages of the present invention more apparent. It should be understood that the specific embodiments described herein are for purposes of illustration only and are not intended to limit the scope of the invention.
In a first aspect, the invention provides a preparation method of a responsive gel temporary plugging agent suitable for a high-temperature oil reservoir, comprising the following steps:
s1, dissolving an aldehyde cross-linking agent into a first organic solvent containing inorganic alkali to obtain a first mixed solution;
S2, dissolving metal salt and high molecular organic amine into a second organic solvent to obtain a second mixed solution;
and S3, uniformly mixing the first mixed solution and the second mixed solution to obtain the responsive gel temporary plugging agent.
The responsive gel temporary plugging agent can be prepared by directly mixing raw materials, and the obtained gelled solution has the advantages of low viscosity and easiness in pumping; after the gel solution is pumped into the stratum, the gel solution can be formed into gel with certain strength in situ after reacting for a certain time in the high-temperature stratum (120-160 ℃), and can be used as temporary plugging agent in the drilling and oil extraction processes; the gel disclosed by the invention can be used for breaking gel by combining processes such as acidification, acid fracturing and the like, the viscosity of the gel solution after breaking gel is low, the blocking removal rate can reach more than 95% under the action of acid, the gel breaking solution has no residue and high surface activity, the implementation of a flowback or fracturing displacement integrated process of the gel breaking solution is facilitated, and the damage to a reservoir is small; the raw materials of the invention are low in price and easy to obtain, the alkali and the solvent are optimized to realize uniform dispersion of substances (inorganic substances and organic substances) in the raw materials, the preparation method of the gel solution is simple, chemical synthesis is not needed, and the gel solution is easy to prepare in the field of oil and gas fields.
In this embodiment, the aldehyde crosslinking agent includes at least one of formaldehyde, paraformaldehyde (POM), benzaldehyde, and urotropine. In combination with practical problems such as transportation, POM having a polymerization degree of 8 to 10 is preferable.
The invention is not limited to the kind of inorganic base, and the main function of the invention is to prepare a first organic solvent containing inorganic base, dissolve aldehyde cross-linking agent, and the invention can be selected according to the actual situation by the person skilled in the art, for example, the inorganic base can be ammonia water, sodium hydroxide, potassium hydroxide, etc.
In this embodiment, the first organic solvent is methanol.
In this embodiment, the concentration of the inorganic base in the first organic solvent solution containing the inorganic base is 0.01 to 5wt%, more preferably 0.1 to 1wt%, still more preferably 0.1wt%.
In this embodiment, the mass ratio of the aldehyde crosslinking agent to the first organic solvent containing an inorganic base is 1:1 to 10. Too low a proportion of methanol results in reduced solubility of the aldehyde crosslinking agent in methanol, while too high a proportion of methanol results in a system that is difficult to gel at high temperatures. Preferably 1:1 to 7.
In this embodiment, the polymer organic amine includes at least one of polyether diamine, polyethylene imine, and chitosan. For example, polyetherdiamines include, but are not limited to, polyetheramine ED-600, polyetheramine ED-900, polyetheramine ED-2003, and the like.
In the invention, at least one of cations in the metal salt is a transition metal ion with coordination ability, which can catalyze imine bond to form a triazine cross-linked structure at high temperature. The specific type of the transition metal cation in the metal salt is not limited, and may be Ca 2+、Zn2+、Al3+、Fe2+、Fe3+、Cu2+、Ge4+, for example. More specifically, the metal salts include, but are not limited to, calcium chloride, zinc chloride, aluminum chloride, germanium chloride, copper chloride, ferric ammonium sulfate, ferric chloride, ferrous chloride, and the like.
In this embodiment, the molar ratio of the metal salt to the polymer organic amine is 0.1 to 5:1. If the molar ratio is too low, the metal ions in the system cannot play a role in catalysis and cannot form gel; if the molar ratio is too high, the coordination bond formed by the metal ion and the imine bond is too strong to form gel through catalysis. Preferably 0.2 to 1:1.
In this embodiment, the second organic solvent is at least one of ethylene glycol phenyl ether (JS-EPh), N-Dimethylformamide (DMF), dimethyl sulfoxide (DMSO), and N-methylpyrrolidone (NMP). The second organic solvent is favorable for improving the solubility of the high polymer organic amine in a system, and the high-boiling point solvent can increase the applicability of the gel at high temperature.
In this embodiment, the amount of the second organic solvent added is 1 to 10 times the mass of the polymer organic amine. If the addition amount of the organic solvent is too low, the polymer organic amine is not easily dissolved in the organic solvent, and if it is too high, it is difficult to gel. Preferably 1 to 5 times.
In this embodiment, the step of dissolving the metal salt and the polymeric organic amine in the second organic solvent is specifically: after the metal salt is ultrasonically dissolved in the second organic solvent, the macromolecule organic amine is added for ultrasonic dissolution.
In this embodiment, the molar ratio of the aldehyde groups in the aldehyde crosslinking agent to the amino groups in the polymeric organic amine is (0.1 to 10): 1, more preferably (1 to 6): 1, still more preferably (2 to 5): 1.
In a second aspect, the invention provides a responsive gel temporary plugging agent applicable to a high-temperature oil reservoir, which is obtained by the preparation method of the responsive gel temporary plugging agent applicable to the high-temperature oil reservoir.
In a third aspect, the invention provides an application of a responsive gel temporary plugging agent suitable for a high-temperature oil reservoir, and the responsive gel temporary plugging agent suitable for the high-temperature oil reservoir is used as an in-situ temporary plugging agent for oil and gas field drilling and oil recovery processes.
In this embodiment, the temperature at which the responsive gel temporary plugging agent applied to the high-temperature reservoir is applied is 120 to 160 ℃.
In some embodiments of the invention, the suitable temperature is 140 ℃.
In some embodiments of the invention, the gel forming time is from 0.2h to 3h.
Example 1
A preparation method of a responsive gel temporary plugging agent suitable for a high-temperature oil reservoir comprises the following steps:
0.1200g of POM (as monomer,0.004 mol) was dissolved in 0.6000g of methanol solution (0.1 wt% sodium hydroxide in methanol) with stirring to obtain a first mixed solution;
0.0964g of ferric ammonium sulfate (0.0002 mol) and 2.0030g of polyetheramine ED-2003 (0.0010 mol) were dissolved in 3.0000g of NMP to obtain a second mixed solution;
And (3) uniformly mixing and stirring the first mixed solution and the second mixed solution, and standing at 140 ℃ for 30min to form the gel.
Referring to fig. 1, it can be seen from fig. 1 that fig. 1 (a) is a low viscosity gel solution prepared, which is in a liquid state at normal temperature and has low viscosity; after high temperature reaction, gel is formed as shown in fig. 1 (b); after addition of 5mL of hydrochloric acid solution (10 wt%), the gel was completely broken down and broken down into low viscosity small molecule products as shown in FIG. 1 (c).
Referring to fig. 2, it can be seen from fig. 2 that as the temperature increases gradually, the viscosity of the gelling solution decreases gradually, from 20 ℃ to 85 ℃, the viscosity decreases from 57mpa·s to 3mpa·s, and the viscosity of the system is far lower than the requirement of the highest pumping pressure (100 mpa·s) in the heating process in the range, so that the preparation solution can go deep into the crack to respond to gelling and plugging.
Referring to fig. 3, it can be seen from fig. 3 that the glue breaking solution and the raw material have certain surface activity, and the surface tension of both of them show a decreasing trend with increasing mass concentration, and reach a minimum value after a certain concentration. The latex breakers had higher surface activity than the starting materials, and CMC and gamma CMC for the latex breakers were 160mg/L and 27.12mN/m, respectively, indicating that the latex breakers had high surface activity.
Referring to fig. 4, it can be seen from fig. 4 that the gel prepared by the present invention has a rich and complete three-dimensional network structure, the skeleton of the gel can effectively support the gel, a certain strength is displayed to the outside, and the dense pore voids can enable the gel to be saturated with a large amount of liquid.
Example 2
According to the method of example 1, the gel forming temperature, gel forming time, plugging pressure, plugging breakthrough pressure gradient and viscosity at 25 ℃ were measured without adding inorganic salt and with CaCl 2、FeCl3、ZnCl2 instead of NH 4Fe(SO4)2 as inorganic salt, respectively, and the test results are shown in table 1.
TABLE 1 influence of different inorganic salts on the performance of gel temporary plugging agents
( And (3) injection: the NH 4Fe(SO4)2 group is example 1. )
The results in table 1 show that the addition of inorganic salt can obviously improve the gel forming temperature of the thermally responsive gel temporary plugging agent, so that the gel can be used for in-situ temporary plugging of oil reservoirs at 120-160 ℃, and the addition of different inorganic salts can realize the adjustable gel forming time. The prepared gel solution has low viscosity (< 60 mPa.s) at 25 ℃ and is easy to pump. After the glue solution enters the high-temperature response glue formation of the ground layer, the blocking pressure is about 5MPa, and the blocking pressure of the gel without adding inorganic salt is 0.9MPa.
Example 3
The gel temporary plugging agent was prepared according to the method of example 1 using ED-900 instead of ED-2003, and the gel temporary plugging agent was prepared according to the method of comparative example 4, and the presence or absence of residues of CMC, gamma CMC and gel breaking liquid was determined, and the test results are shown in Table 2.
TABLE 2 influence of different macromolecular organic amines on CMC and Gamma CMC before and after breaking the gel product
( And (3) injection: ED-2003 group example 1 ED-900 group was prepared according to the method described in example 1, with ED-900 being added in an amount of 0.9000g; preparation method of T-5000 group as comparative example 4 )
As can be seen from the results of Table 2, the gel-breaking solutions of the temporary plugging agents for gels prepared from ED-2003 and ED-900 as raw materials have higher surface activity than the gel-breaking solutions. However, there is a residue in the gel breaking solution of the temporary plugging agent of the gel prepared by using the polyether triamine T-5000 as a raw material, which is probably because the hydrophobic structure of the structural unit of the T-5000 is dominant, and the residue is separated out from the aqueous hydrochloric acid solution to be insoluble after being decomposed into small molecules.
Example 4
A preparation method of a responsive gel temporary plugging agent suitable for a high-temperature oil reservoir comprises the following steps:
0.4245g of benzaldehyde (0.004 mol) was dissolved in 0.6000g of methanol solution (0.1 wt% sodium hydroxide in methanol) with stirring to obtain a first mixed solution;
0.0366g of cadmium chloride (0.0002 mol) and 1.8000g of polyethyleneimine (0.0010 mol) were dissolved in 3.0000g of DMSO to obtain a second mixed solution;
And (3) uniformly mixing and stirring the first mixed solution and the second mixed solution, and standing at 140 ℃ for 180min to form the gel.
Example 5
A preparation method of a responsive gel temporary plugging agent suitable for a high-temperature oil reservoir comprises the following steps:
0.1200g of POM (as monomer,0.004 mol) was dissolved in 0.6000g of methanol solution (0.1 wt% sodium hydroxide in methanol) with stirring to obtain a first mixed solution;
0.0222g of calcium chloride (0.0002 mol) and 1.0000g of chitosan (the deacetylation degree is more than or equal to 95 percent, and the viscosity is 100 to 200 mPa.s) are dissolved in 3.0000g of DMF to obtain a second mixed solution;
and (3) uniformly mixing and stirring the first mixed solution and the second mixed solution, and standing at 140 ℃ for 25min to form the gel.
Comparative example 1
The temporary blocking agent content and the test temperature were the same as in example 1. The difference is that: comparative example 1 (university of Tianjin (edition of natural science and engineering technology), 2019, 52 (01)) mainly has a sulfonated modified polyacrylamide structure, and is obtained by reacting acrylamide (5 wt%) and 2-acrylamide-2-methylpropanesulfonic acid (0.2 wt%) with 0.25wt% of crosslinking agent N, N-methylenebisacrylamide, 200g/L of solid content, 0.35wt% of thickener xanthan gum, and at 125 ℃ according to the optimal synthesis conditions. After the comparative example 1 is glued, the glue is aged for 2 hours at 140 ℃, and experiments show that the temporary plugging agent is seriously decomposed, the pressure-bearing strength is less than 0.1MPa, and the plugging property is poor; in the embodiment 1 of the invention, under the same condition, the bearing strength is as high as 5MPa, and the plugging performance is excellent.
Comparative example 2
The temporary blocking agent content and the test temperature were the same as in example 1. The difference is that: comparative example 2 (drilling and completion fluids, 2019, 36 (06)) is a polyethyleneimine crosslinked modified polyacrylamide structure. The experimental formula is that the gel solution of 2wt percent of sulfonated polyacrylamide, 1wt percent of polyethyleneimine, 0.02wt percent of thiourea and distilled water has apparent viscosity of 350 mPa.s at 25 ℃ and shear rate of 200s -1, and after curing and gelling for 2 hours at 140 ℃,20 mL of 10wt percent potassium persulfate solution is injected for oxidative gel breaking. Comparative example 2 has a bearing strength of 2MPa and a blocking removal rate of 89% after gel breaking; in contrast, the gelled solution of example 1 of the present invention has an apparent viscosity of less than 57 mPas at 25℃and a shear rate of 200s -1, and has a blocking removal rate of more than 98% after gel breaking with an equal volume of hydrochloric acid solution (5 wt%).
Comparative example 3
The temporary blocking agent content and the test temperature were the same as in example 1. The difference is that: the material in comparative example 3 (CN 108949131 a) is a cross-linked polyether amine with molecular weight less than 1000 and dialdehyde under alkaline condition. In one example, a 5wt% solution of polyetheramine D400 was mixed with a 10wt% solution of glyoxal at ph=10 and finally allowed to gel at 70 ℃, but at 140 ℃, the system was liquid and not capable of plugging.
Referring to fig. 5, it can be seen from fig. 5 that at normal temperature, the pressure of the gel in comparative example 3 was brittle and broken when compressed by only 12%, and the maximum pressure was 0.21MPa, although the pressure of the gel was gradually increased with the increase of the pressure. Such aminal gels were rendered thermally responsive by the addition of metal salts in example 1 and increased the pressure-bearing properties of the gel to 5MPa without breaking. The gel is compressed along with the continuous compression of the response gel, the supporting structure of the gel is extruded continuously, when the metal gel is compressed to 70%, the supporting structure is extruded to the limit, after the metal gel is further compressed to 80%, the compressed supporting structure is the tightest, the bearing performance is further improved, and the highest tolerance pressure of the metal gel can reach 5MPa.
Comparative example 4
The temporary blocking agent content and the test temperature were the same as in example 1. Except that 0.1200g of paraformaldehyde (0.004 mol) and 5.0000g of polyetheramine T-5000 (0.0010 mol) were dissolved in 6g of NMP at 85℃and gelled in 3min after cooling to room temperature, then 0.0964g of ferric ammonium sulphate (0.0002 mol) solid were added and mixed together by mechanical stirring, at which time the ferric ions break down the imine bond in 24h by complexation, macroscopically appearing as a gel to a glue solution. Finally, the glue solution is placed at 140 ℃ for 40min, and the glue solution can be formed again after the coordination bonds are destroyed at high temperature. The system has complex preparation conditions and is not suitable for field application.
The above-described embodiments of the present invention do not limit the scope of the present invention. Any other corresponding changes and modifications made in accordance with the technical idea of the present invention shall be included in the scope of the claims of the present invention.
Claims (5)
1. The preparation method of the responsive gel temporary plugging agent suitable for the high-temperature oil reservoir is characterized by comprising the following steps of:
Dissolving an aldehyde cross-linking agent into a first organic solvent containing inorganic alkali to obtain a first mixed solution;
Dissolving metal salt and high molecular organic amine into a second organic solvent to obtain a second mixed solution;
Uniformly mixing the first mixed solution and the second mixed solution to obtain a responsive gel temporary plugging agent;
Wherein the aldehyde cross-linking agent comprises at least one of formaldehyde, paraformaldehyde, benzaldehyde and urotropine; the first organic solvent is methanol; in the first organic solvent solution containing inorganic alkali, the concentration of the inorganic alkali is 0.01-5wt%, and the mass ratio of the aldehyde cross-linking agent to the first organic solvent containing inorganic alkali is 1:1-10;
the high molecular organic amine comprises at least one of polyether diamine, polyethyleneimine and chitosan; at least one kind of cation in the metal salt is a transition state metal ion with coordination ability; the second organic solvent is at least one of ethylene glycol phenyl ether, N-dimethylformamide, dimethyl sulfoxide and N-methylpyrrolidone; the molar ratio of the metal salt to the high molecular organic amine is 0.1-5:1; the addition amount of the second organic solvent is 1-10 times of the mass of the high molecular organic amine;
The molar ratio of aldehyde groups in the aldehyde crosslinking agent to amino groups in the high molecular organic amine is (0.1-10): 1.
2. The method for preparing the responsive gel temporary plugging agent applicable to the high-temperature oil reservoir according to claim 1, wherein the polyether diamine is at least one of polyether amine ED-600, polyether amine ED-900 and polyether amine ED-2003; the transition metal ion is at least one of Ca 2+、Zn2+、Al3+、Fe2+、Fe3+、Cu2+、Ge4+.
3. The responsive gel temporary plugging agent for high-temperature oil reservoirs according to claim 1, wherein the responsive gel temporary plugging agent for high-temperature oil reservoirs is obtained by the preparation method of the responsive gel temporary plugging agent for high-temperature oil reservoirs according to any one of claims 1-2.
4. The use of a responsive gel temporary plugging agent for a high temperature reservoir according to claim 3, wherein the responsive gel temporary plugging agent for a high temperature reservoir is used as an in situ temporary plugging agent in oil and gas field drilling and production processes.
5. The application of the responsive gel temporary plugging agent applicable to the high-temperature oil reservoir according to claim 4, wherein the applicable temperature of the responsive gel temporary plugging agent applicable to the high-temperature oil reservoir is 120-160 ℃.
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| CN115160500A (en) * | 2022-07-27 | 2022-10-11 | 中国地质大学（武汉） | Multi-response controllable crosslinking degradation gel particle temporary plugging agent and preparation method and application thereof |
| CN115404062B (en) * | 2022-08-30 | 2023-10-27 | 长江大学 | PH value and temperature dual-response supermolecule gel temporary plugging agent, preparation method and application thereof, and temporary plugging diverting fracturing method |
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| CN101121880A (en) * | 2007-08-01 | 2008-02-13 | 成都市互利达实业有限公司 | Natural macromolecule modified starch profile control agent for oil field |
| CN104449618A (en) * | 2015-01-06 | 2015-03-25 | 西南石油大学 | Temperature-resisting salt-tolerant high-temperature self-cross-linking onsite polymerization water plugging gel |
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