CN111022011A - Construction method of foamable resin sand consolidation agent for argillaceous fine silt oil reservoir - Google Patents
Construction method of foamable resin sand consolidation agent for argillaceous fine silt oil reservoir Download PDFInfo
- Publication number
- CN111022011A CN111022011A CN201911221506.4A CN201911221506A CN111022011A CN 111022011 A CN111022011 A CN 111022011A CN 201911221506 A CN201911221506 A CN 201911221506A CN 111022011 A CN111022011 A CN 111022011A
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- Prior art keywords
- sand
- agent
- slug
- foamable resin
- consolidation
- Prior art date
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- 239000004576 sand Substances 0.000 title claims abstract description 285
- 239000003795 chemical substances by application Substances 0.000 title claims abstract description 144
- 238000007596 consolidation process Methods 0.000 title claims abstract description 139
- 229920005989 resin Polymers 0.000 title claims abstract description 96
- 239000011347 resin Substances 0.000 title claims abstract description 96
- 238000010276 construction Methods 0.000 title claims abstract description 42
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims abstract description 88
- 229910052757 nitrogen Inorganic materials 0.000 claims abstract description 44
- 238000004519 manufacturing process Methods 0.000 claims abstract description 34
- 238000000034 method Methods 0.000 claims abstract description 20
- 239000006260 foam Substances 0.000 claims abstract description 18
- 230000002579 anti-swelling effect Effects 0.000 claims abstract description 15
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 14
- 239000004088 foaming agent Substances 0.000 claims abstract description 14
- 230000002401 inhibitory effect Effects 0.000 claims abstract description 14
- 239000007864 aqueous solution Substances 0.000 claims abstract description 10
- 238000005187 foaming Methods 0.000 claims abstract description 4
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N silicon dioxide Inorganic materials O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims description 248
- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonia chloride Chemical compound [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 claims description 34
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 31
- 239000003921 oil Substances 0.000 claims description 30
- 239000007788 liquid Substances 0.000 claims description 21
- 235000019270 ammonium chloride Nutrition 0.000 claims description 17
- 239000006087 Silane Coupling Agent Substances 0.000 claims description 11
- 238000006073 displacement reaction Methods 0.000 claims description 10
- 239000003381 stabilizer Substances 0.000 claims description 10
- 229920000877 Melamine resin Polymers 0.000 claims description 8
- 239000002994 raw material Substances 0.000 claims description 7
- KXGFMDJXCMQABM-UHFFFAOYSA-N 2-methoxy-6-methylphenol Chemical compound [CH]OC1=CC=CC([CH])=C1O KXGFMDJXCMQABM-UHFFFAOYSA-N 0.000 claims description 6
- RTZKZFJDLAIYFH-UHFFFAOYSA-N Diethyl ether Chemical compound CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 claims description 6
- KRKNYBCHXYNGOX-UHFFFAOYSA-N citric acid Chemical compound OC(=O)CC(O)(C(O)=O)CC(O)=O KRKNYBCHXYNGOX-UHFFFAOYSA-N 0.000 claims description 6
- 238000004140 cleaning Methods 0.000 claims description 6
- 229920001568 phenolic resin Polymers 0.000 claims description 6
- 239000005011 phenolic resin Substances 0.000 claims description 6
- DGAQECJNVWCQMB-PUAWFVPOSA-M Ilexoside XXIX Chemical compound C[C@@H]1CC[C@@]2(CC[C@@]3(C(=CC[C@H]4[C@]3(CC[C@@H]5[C@@]4(CC[C@@H](C5(C)C)OS(=O)(=O)[O-])C)C)[C@@H]2[C@]1(C)O)C)C(=O)O[C@H]6[C@@H]([C@H]([C@@H]([C@H](O6)CO)O)O)O.[Na+] DGAQECJNVWCQMB-PUAWFVPOSA-M 0.000 claims description 5
- 150000002191 fatty alcohols Chemical class 0.000 claims description 5
- 239000002245 particle Substances 0.000 claims description 5
- 239000011734 sodium Substances 0.000 claims description 5
- 229910052708 sodium Inorganic materials 0.000 claims description 5
- WYTZZXDRDKSJID-UHFFFAOYSA-N (3-aminopropyl)triethoxysilane Chemical compound CCO[Si](OCC)(OCC)CCCN WYTZZXDRDKSJID-UHFFFAOYSA-N 0.000 claims description 4
- XDLMVUHYZWKMMD-UHFFFAOYSA-N 3-trimethoxysilylpropyl 2-methylprop-2-enoate Chemical compound CO[Si](OC)(OC)CCCOC(=O)C(C)=C XDLMVUHYZWKMMD-UHFFFAOYSA-N 0.000 claims description 4
- VSCWAEJMTAWNJL-UHFFFAOYSA-K aluminium trichloride Chemical compound Cl[Al](Cl)Cl VSCWAEJMTAWNJL-UHFFFAOYSA-K 0.000 claims description 4
- 125000003178 carboxy group Chemical group [H]OC(*)=O 0.000 claims description 4
- 229920002678 cellulose Polymers 0.000 claims description 4
- 239000001913 cellulose Substances 0.000 claims description 4
- 239000004094 surface-active agent Substances 0.000 claims description 4
- DUIOKRXOKLLURE-UHFFFAOYSA-N 2-octylphenol Chemical compound CCCCCCCCC1=CC=CC=C1O DUIOKRXOKLLURE-UHFFFAOYSA-N 0.000 claims description 3
- PMZURENOXWZQFD-UHFFFAOYSA-L Sodium Sulfate Chemical compound [Na+].[Na+].[O-]S([O-])(=O)=O PMZURENOXWZQFD-UHFFFAOYSA-L 0.000 claims description 3
- XSQUKJJJFZCRTK-UHFFFAOYSA-N Urea Chemical compound NC(N)=O XSQUKJJJFZCRTK-UHFFFAOYSA-N 0.000 claims description 3
- -1 alkyl glycoside Chemical class 0.000 claims description 3
- 229940051841 polyoxyethylene ether Drugs 0.000 claims description 3
- 229920000056 polyoxyethylene ether Polymers 0.000 claims description 3
- 229910052938 sodium sulfate Inorganic materials 0.000 claims description 3
- 235000011152 sodium sulphate Nutrition 0.000 claims description 3
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 claims description 3
- BPSIOYPQMFLKFR-UHFFFAOYSA-N trimethoxy-[3-(oxiran-2-ylmethoxy)propyl]silane Chemical compound CO[Si](OC)(OC)CCCOCC1CO1 BPSIOYPQMFLKFR-UHFFFAOYSA-N 0.000 claims description 3
- 239000004711 α-olefin Substances 0.000 claims description 3
- RCEAADKTGXTDOA-UHFFFAOYSA-N OS(O)(=O)=O.CCCCCCCCCCCC[Na] Chemical compound OS(O)(=O)=O.CCCCCCCCCCCC[Na] RCEAADKTGXTDOA-UHFFFAOYSA-N 0.000 claims description 2
- 239000002202 Polyethylene glycol Substances 0.000 claims description 2
- 239000004372 Polyvinyl alcohol Substances 0.000 claims description 2
- 229920001807 Urea-formaldehyde Polymers 0.000 claims description 2
- GZCGUPFRVQAUEE-SLPGGIOYSA-N aldehydo-D-glucose Chemical compound OC[C@@H](O)[C@@H](O)[C@H](O)[C@@H](O)C=O GZCGUPFRVQAUEE-SLPGGIOYSA-N 0.000 claims description 2
- LFVGISIMTYGQHF-UHFFFAOYSA-N ammonium dihydrogen phosphate Chemical compound [NH4+].OP(O)([O-])=O LFVGISIMTYGQHF-UHFFFAOYSA-N 0.000 claims description 2
- 229910000387 ammonium dihydrogen phosphate Inorganic materials 0.000 claims description 2
- 239000004202 carbamide Substances 0.000 claims description 2
- 229910052681 coesite Inorganic materials 0.000 claims description 2
- 150000001875 compounds Chemical class 0.000 claims description 2
- 229910052906 cristobalite Inorganic materials 0.000 claims description 2
- 229930182470 glycoside Natural products 0.000 claims description 2
- 235000019837 monoammonium phosphate Nutrition 0.000 claims description 2
- 229920001495 poly(sodium acrylate) polymer Polymers 0.000 claims description 2
- 229920001223 polyethylene glycol Polymers 0.000 claims description 2
- 229920002689 polyvinyl acetate Polymers 0.000 claims description 2
- 239000011118 polyvinyl acetate Substances 0.000 claims description 2
- 229920002451 polyvinyl alcohol Polymers 0.000 claims description 2
- 229910052710 silicon Inorganic materials 0.000 claims description 2
- 239000010703 silicon Substances 0.000 claims description 2
- 239000000377 silicon dioxide Substances 0.000 claims description 2
- NNMHYFLPFNGQFZ-UHFFFAOYSA-M sodium polyacrylate Chemical compound [Na+].[O-]C(=O)C=C NNMHYFLPFNGQFZ-UHFFFAOYSA-M 0.000 claims description 2
- 239000007790 solid phase Substances 0.000 claims description 2
- 229910052682 stishovite Inorganic materials 0.000 claims description 2
- 229910052905 tridymite Inorganic materials 0.000 claims description 2
- 230000035699 permeability Effects 0.000 abstract description 29
- 230000002265 prevention Effects 0.000 abstract description 13
- 239000000126 substance Substances 0.000 abstract description 10
- 239000011148 porous material Substances 0.000 abstract description 9
- 230000008569 process Effects 0.000 abstract description 9
- DBMJMQXJHONAFJ-UHFFFAOYSA-M Sodium laurylsulphate Chemical compound [Na+].CCCCCCCCCCCCOS([O-])(=O)=O DBMJMQXJHONAFJ-UHFFFAOYSA-M 0.000 description 19
- 230000000694 effects Effects 0.000 description 18
- 238000003756 stirring Methods 0.000 description 15
- 238000002347 injection Methods 0.000 description 14
- 239000007924 injection Substances 0.000 description 14
- 239000001768 carboxy methyl cellulose Substances 0.000 description 11
- 235000019333 sodium laurylsulphate Nutrition 0.000 description 9
- DPXJVFZANSGRMM-UHFFFAOYSA-N acetic acid;2,3,4,5,6-pentahydroxyhexanal;sodium Chemical compound [Na].CC(O)=O.OCC(O)C(O)C(O)C(O)C=O DPXJVFZANSGRMM-UHFFFAOYSA-N 0.000 description 8
- 239000003129 oil well Substances 0.000 description 8
- 235000019812 sodium carboxymethyl cellulose Nutrition 0.000 description 8
- 229920001027 sodium carboxymethylcellulose Polymers 0.000 description 8
- 238000002360 preparation method Methods 0.000 description 7
- 238000005086 pumping Methods 0.000 description 7
- 229920003180 amino resin Polymers 0.000 description 6
- 239000006004 Quartz sand Substances 0.000 description 5
- 230000014759 maintenance of location Effects 0.000 description 5
- 239000003960 organic solvent Substances 0.000 description 5
- 239000000843 powder Substances 0.000 description 5
- 241000251468 Actinopterygii Species 0.000 description 4
- LRHPLDYGYMQRHN-UHFFFAOYSA-N N-Butanol Chemical compound CCCCO LRHPLDYGYMQRHN-UHFFFAOYSA-N 0.000 description 4
- 230000009471 action Effects 0.000 description 4
- 230000008901 benefit Effects 0.000 description 4
- 230000000903 blocking effect Effects 0.000 description 4
- 239000000243 solution Substances 0.000 description 4
- QTBSBXVTEAMEQO-UHFFFAOYSA-N Acetic acid Chemical compound CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 description 3
- 229920002134 Carboxymethyl cellulose Polymers 0.000 description 3
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 description 3
- XEKOWRVHYACXOJ-UHFFFAOYSA-N Ethyl acetate Chemical compound CCOC(C)=O XEKOWRVHYACXOJ-UHFFFAOYSA-N 0.000 description 3
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical compound OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 description 3
- 241001023442 Populus suaveolens Species 0.000 description 3
- 235000010948 carboxy methyl cellulose Nutrition 0.000 description 3
- 239000008112 carboxymethyl-cellulose Substances 0.000 description 3
- 229920006317 cationic polymer Polymers 0.000 description 3
- 239000002734 clay mineral Substances 0.000 description 3
- 239000011248 coating agent Substances 0.000 description 3
- 238000000576 coating method Methods 0.000 description 3
- 238000007906 compression Methods 0.000 description 3
- 230000006835 compression Effects 0.000 description 3
- 238000005553 drilling Methods 0.000 description 3
- 230000000087 stabilizing effect Effects 0.000 description 3
- KFZMGEQAYNKOFK-UHFFFAOYSA-N Isopropanol Chemical compound CC(C)O KFZMGEQAYNKOFK-UHFFFAOYSA-N 0.000 description 2
- 239000002253 acid Substances 0.000 description 2
- 239000011230 binding agent Substances 0.000 description 2
- 230000033558 biomineral tissue development Effects 0.000 description 2
- 230000008859 change Effects 0.000 description 2
- 238000006243 chemical reaction Methods 0.000 description 2
- 239000007822 coupling agent Substances 0.000 description 2
- 239000010779 crude oil Substances 0.000 description 2
- 238000007865 diluting Methods 0.000 description 2
- 239000006185 dispersion Substances 0.000 description 2
- 239000003822 epoxy resin Substances 0.000 description 2
- 238000009472 formulation Methods 0.000 description 2
- 239000007849 furan resin Substances 0.000 description 2
- 239000007789 gas Substances 0.000 description 2
- 239000004620 low density foam Substances 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 239000000203 mixture Substances 0.000 description 2
- 229920000647 polyepoxide Polymers 0.000 description 2
- 239000010865 sewage Substances 0.000 description 2
- 238000005507 spraying Methods 0.000 description 2
- 230000007480 spreading Effects 0.000 description 2
- 238000003892 spreading Methods 0.000 description 2
- YSUQLAYJZDEMOT-UHFFFAOYSA-N 2-(butoxymethyl)oxirane Chemical compound CCCCOCC1CO1 YSUQLAYJZDEMOT-UHFFFAOYSA-N 0.000 description 1
- GOJUJUVQIVIZAV-UHFFFAOYSA-N 2-amino-4,6-dichloropyrimidine-5-carbaldehyde Chemical group NC1=NC(Cl)=C(C=O)C(Cl)=N1 GOJUJUVQIVIZAV-UHFFFAOYSA-N 0.000 description 1
- 241000237858 Gastropoda Species 0.000 description 1
- 230000032683 aging Effects 0.000 description 1
- 239000003513 alkali Substances 0.000 description 1
- 230000004888 barrier function Effects 0.000 description 1
- 230000005465 channeling Effects 0.000 description 1
- 239000004927 clay Substances 0.000 description 1
- 239000002131 composite material Substances 0.000 description 1
- 238000004132 cross linking Methods 0.000 description 1
- 239000003431 cross linking reagent Substances 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000018109 developmental process Effects 0.000 description 1
- 239000002283 diesel fuel Substances 0.000 description 1
- MTHSVFCYNBDYFN-UHFFFAOYSA-N diethylene glycol Chemical compound OCCOCCO MTHSVFCYNBDYFN-UHFFFAOYSA-N 0.000 description 1
- 239000002270 dispersing agent Substances 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000005530 etching Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 230000002349 favourable effect Effects 0.000 description 1
- 238000001914 filtration Methods 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 230000006870 function Effects 0.000 description 1
- 229930182478 glucoside Natural products 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 230000036571 hydration Effects 0.000 description 1
- 238000006703 hydration reaction Methods 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- 238000001764 infiltration Methods 0.000 description 1
- 230000008595 infiltration Effects 0.000 description 1
- 230000001788 irregular Effects 0.000 description 1
- 150000002576 ketones Chemical class 0.000 description 1
- 230000005012 migration Effects 0.000 description 1
- 238000013508 migration Methods 0.000 description 1
- 238000002156 mixing Methods 0.000 description 1
- 239000000178 monomer Substances 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 238000006116 polymerization reaction Methods 0.000 description 1
- 230000002035 prolonged effect Effects 0.000 description 1
- 238000010926 purge Methods 0.000 description 1
- 230000036632 reaction speed Effects 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
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- 239000002689 soil Substances 0.000 description 1
- 238000001179 sorption measurement Methods 0.000 description 1
- 230000008961 swelling Effects 0.000 description 1
- 238000001308 synthesis method Methods 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
- 229920001187 thermosetting polymer Polymers 0.000 description 1
- 231100000331 toxic Toxicity 0.000 description 1
- 230000002588 toxic effect Effects 0.000 description 1
- 238000005406 washing Methods 0.000 description 1
- 239000001993 wax Substances 0.000 description 1
- 230000004580 weight loss Effects 0.000 description 1
Images
Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
-
- 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
- C09K8/56—Compositions for consolidating loose sand or the like around wells without excessively decreasing the permeability thereof
- C09K8/57—Compositions based on water or polar solvents
- C09K8/572—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
- C09K8/56—Compositions for consolidating loose sand or the like around wells without excessively decreasing the permeability thereof
- C09K8/57—Compositions based on water or polar solvents
- C09K8/575—Compositions based on water or polar solvents containing organic compounds
- C09K8/5751—Macromolecular compounds
- C09K8/5755—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
- C09K8/56—Compositions for consolidating loose sand or the like around wells without excessively decreasing the permeability thereof
- C09K8/57—Compositions based on water or polar solvents
- C09K8/575—Compositions based on water or polar solvents containing organic compounds
- C09K8/5751—Macromolecular compounds
- C09K8/5756—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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/02—Subsoil filtering
-
- 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
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Chemical & Material Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- Geochemistry & Mineralogy (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Inorganic Chemistry (AREA)
- Soil Conditioners And Soil-Stabilizing Materials (AREA)
- Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
- Investigation Of Foundation Soil And Reinforcement Of Foundation Soil By Compacting Or Drainage (AREA)
Abstract
The invention relates to a construction method of a foamable resin sand consolidation agent for a argillaceous fine silt oil reservoir, belonging to the technical field of chemical sand prevention of oil fields. The construction method of the foamable resin sand consolidation agent for the argillaceous fine silt oil reservoir comprises the following steps: (1) injecting a pretreatment slug into the sand producing layer; the pretreatment slug is an aqueous solution comprising an anti-swelling sand-inhibiting agent; (2) simultaneously injecting foamable resin sand consolidation agent and nitrogen into the sand production position to form a sand consolidation slug; the foamable resin sand setting agent comprises a foamable cementing agent, a foaming agent and a curing agent for bonding sand grains; (3) and then injected to displace the slug. The foaming cementing agent and foaming agent for bonding sand grains in the sand consolidation slug can be mixed with nitrogen to form foam, and the nitrogen is used as a pore-expanding agent, so that a large number of pore passages can be formed when the foaming resin sand consolidation agent is contacted with formation sand to bond the sand grains, and the permeability is ensured. The construction method is simple, the construction process is safe and simple, and the application is wide.
Description
Technical Field
The invention relates to a construction method of a foamable resin sand consolidation agent for a argillaceous fine silt oil reservoir, belonging to the technical field of chemical sand prevention of oil fields.
Background
Sand, wax and water are the key research points of oil extraction engineering technical workers, and sand production not only shortens the service life of an oil well, abrades underground and ground equipment, and bridges or blocks a well bore, but also reduces the yield of the oil well, even forces the oil well to stop production, seriously influences the normal production of the oil field, even causes the collapse of the oil well, and the scrapping of the oil well.
The unconsolidated sandstone reservoir has wide distribution and rich reserves and plays an important role in oil exploitation, but the unconsolidated sandstone reservoir is easy to produce sand in the production process, especially a high-argillaceous unconsolidated sandstone reservoir which has the characteristics of high argillaceous content and high fine silt content, and the sand prevention validity period of the reservoir is far lower than the average sand prevention validity period due to formation sand production and blockage in the production process, so that the sand prevention exploitation effect of the reservoir is seriously limited. Therefore, effective sand prevention for the sand production well is the primary measure for ensuring normal production of the oil field.
With the continuous development of the sand control technology of the oil field, two categories of chemical sand control and mechanical sand control are gradually formed. Although the mechanical sand control has long effective period, the problem of stratum sand production is not solved fundamentally, the prevention and control capability of the mechanical sand control on fine silt is relatively weak, and the mechanical sand control cannot be adopted for casing deformation wells. The chemical sand control method used in China mainly comprises resin liquid sand control and resin coating sand, and the cementing agent mainly comprises resin. Despite the many advantages of conventional resin sand control, there are a number of problems that need to be solved. For example, in the case of the underground resin synthesis method, monomers are injected, the polymerization reaction is difficult to be carried out in the underground in a balanced manner, the crosslinking reaction is incomplete, and the consolidation strength after sand control does not reach the sand control standard, so that the sand control fails or the effective period is shortened. When the resin is synthesized on the ground, the resin has high viscosity, needs to be added with an organic solvent, has high cost and pollution, and has high reaction speed after being added with a curing agent, so that the curing agent can be started to be cured on the way of pumping into a stratum, thereby blocking machines and tools. In addition, the permeability of most of the cured resin is seriously reduced, and only 40 to 60 percent of the original permeability can be maintained, so that the yield is reduced, the resin is blocked seriously, and petroleum cannot be produced. The problems of short validity period, poor medium resistance, troublesome post-treatment after sand control failure and the like commonly exist in the conventional chemical sand control system.
Chinese patent CN105199698A discloses a novel low-temperature coating sand, which is prepared from A, B two components according to the weight ratio of 1:1, wherein the A component comprises: quartz sand, a binder, a coupling agent, a dispersant and an accelerator; the component B comprises: the novel low-temperature coating sand is high in curing speed, high in early strength and wide in applicable oil layer temperature range, and the product can generate high early strength after 24 hours at the temperature of 45-260 ℃ and is short in waiting time. The Chinese patent CN101747882A is a curing system with high reaction activity under water environment and low temperature conditions formed by mixing low-temperature precoated sand taking composite phenolic-epoxy resin as a cementing agent and a water-soluble curing agent, and the low-temperature precoated sand can be cured within the temperature range of 30-50 ℃ under the action of the water-soluble curing agent, so that the formed consolidated body has high strength and permeability, has strong temperature resistance, ageing resistance and scouring resistance, and can meet the sand control requirements of low-temperature oil reservoirs. The two systems have high activity and high curing speed, and have high curing risk before being injected into a stratum, and the construction difficulty is high.
U.S. Pat. No. 4,129,85 discloses a scheme for controlling the migration of fine sand by treating a near-wellbore zone with a thermosetting phenolic resin (with a concentration of about 10-20%) diluted with an organic solvent such as methanol, ethanol, isopropanol, ketone, glycol ether, etc., to form a resin film on the surface of formation sand particles, which is then cured to form an insoluble resin; US7114570 discloses a technical solution of diluting curable resins such as phenolic resin, furan resin, epoxy resin and the like with organic solvents such as glycidyl butyl ether, butanol and the like, treating a near-well zone, forming a resin film on the surface of formation sand grains, and stabilizing and loosening the formation; US5522460 discloses a technical scheme for sand control construction by diluting furan resin (with a concentration of about 30-90%) with organic solvents such as n-butanol, acetic acid, ethyl acetate and the like. However, the organic solvent adopted by the methods is high in price, inflammable and toxic, so that the sand prevention cost is greatly increased on one hand, the risk of field construction is increased on the other hand, the damage to the stratum permeability is large, particularly, the risk of blocking the stratum exists, and the method cannot be widely applied to oil field chemical sand prevention.
In addition, in the chemical sand control methods, most of the construction methods of the resin sand consolidation agent are that the resin sand consolidation agent is directly injected into a sand production layer, so that the resin sand consolidation agent is contacted with sand after entering the sand production layer for consolidation.
Disclosure of Invention
The invention aims to provide a construction method of a foamable resin sand consolidation agent for a muddy fine silt reservoir, which can have better permeability after sand consolidation.
The technical scheme of the invention is as follows:
a construction method of a foamable resin sand consolidation agent for a argillaceous fine silt oil reservoir comprises the following steps:
(1) injecting a pretreatment slug into the sand producing layer; the pretreatment slug is an aqueous solution comprising an anti-swelling sand-inhibiting agent;
(2) simultaneously injecting foamable resin sand consolidation agent and nitrogen into the sand production position to form a sand consolidation slug; the foamable resin sand setting agent comprises a foamable cementing agent, a foaming agent and a curing agent for bonding sand grains;
(3) and then injected to displace the slug.
The construction method of the foamable resin sand consolidation agent for the argillaceous fine silt oil reservoir can complete construction only by sequentially injecting the pretreatment slug, the sand consolidation slug and the displacement slug, is simple and convenient, is suitable for the sand control requirements of a common straight well, a long-well-section horizontal well, a highly-deviated well, a side drilling well and a casing change well, and is suitable for secondary sand control after mechanical sand control failure, and has safe and simple construction process and wide application.
In the construction method of the foamable resin sand consolidation agent for the argillaceous fine silt oil reservoir, the sand consolidation slug is formed by simultaneously injecting the foamable resin sand consolidation agent and nitrogen, the foamable cementing agent and foaming agent for bonding sand grains in the sand consolidation slug and the nitrogen can form foam, and the nitrogen can also be used as a pore-expanding agent, so that a large number of pore canals can be formed after the foamable resin sand consolidation agent is contacted with formation sand, and the good permeability is ensured after sand consolidation. The sand consolidation agent can form foam, has the characteristics of low density, good stability, high safety and the like, can be applied to sand control of long-well-section horizontal wells and irregular well bores, is stable in a shaft and cannot be consolidated in the well bores. The sand control device is particularly suitable for secondary sand control after mechanical sand control failure, does not block sieve pores, and can uniformly enter a stratum. In the low-temperature stratum at the temperature of 35-90 ℃, the strength of the consolidated core reaches more than 5MPa, and the sand consolidation agent forming foam can be uniformly injected through a Jamin effect. The sand control agent is suitable for sand control of fine silt oil reservoirs, resin is used for solidifying sand grains, and nitrogen realizes hole expansion, and has high strength and permeability. Has good compatibility with formation fluid, better tolerance to water, diesel oil, alkali and salt, and is suitable for the formation mineralization degree of 10 multiplied by 104The stratum below mg/L.
The construction method of the foamable resin sand consolidation agent for the argillaceous fine silt oil reservoir has certain advantages in the aspects of horizontal well sand prevention and heterogeneous stratum sand prevention. The foamable resin sand consolidation agent contains foam, has low density, and can be uniformly injected into a special well with a long production well section and a complex well body structure; the system infiltration caused by the liquid gravity difference can be prevented; in addition, due to the foam Jamin effect, the foam can be uniformly injected into high-permeability and low-permeability stratums. In addition, compared with a resin solution sand consolidation system, the sand consolidation system disclosed by the invention can be used for plugging in a high-permeability stratum, preventing fingering and being suitable for chemical sand control of a heterogeneous stratum.
It can be understood that each slug is injected through the wellbore, the wellbore can be cleaned before injection to ensure that each slug is smoothly injected into the sand production layer, and preferably, in the step (1), before the pretreated slug is injected into the sand production layer, a cleaning slug is first injected into the wellbore, and the cleaning slug is hot water at 70-90 ℃.
The shaft is cleaned by hot water (70-90 ℃) in a circulating way, oil stains can be removed, and the shaft is cleaned in a circulating way until the water quality of an inlet and an outlet is consistent.
The anti-swelling sand-inhibiting agent in the pretreated slug can effectively shrink the clay mineral which is subjected to hydration swelling. The method has obvious improvement effect on the reservoir property of a reservoir which is damaged, and has excellent functions of inhibiting the expansion of clay minerals, stabilizing the clay minerals and preventing the damage of the reservoir. Preferably, in the step (1), the mass fraction of the anti-swelling sand-inhibiting agent in the aqueous solution is 0.5-1.5%. The anti-swelling and stabilizing of the clay can be effectively carried out in the pretreatment stage by reasonably adjusting and optimizing the dosage of the anti-swelling sand-inhibiting agent.
Preferably, in step (1), the pretreated slug further comprises a surfactant. The surfactant in the pretreatment slug can remove crude oil and blockage on the surfaces of sieve pores and sand grains through the cleaning action and the pretreatment action.
The surfactant is not limited as long as it can remove crude oil and clogging on the surface of the mesh and the sand, and may be, for example, Sodium Dodecyl Sulfate (SDS).
Preferably, in step (1), the pretreatment slug further comprises a curing agent; the mass fraction of the curing agent in the aqueous solution is 0.2-0.4%. The curing agent in the pretreated slug can enable the curing agent to be adsorbed on the surface of sand grains in advance, so that the sand-fixing agent in the subsequent sand-fixing slug is easy to bond, and the sand-fixing effect is ensured.
The type of the curing agent is not limited as long as it can contribute to the consolidation of the sand consolidation agent in the sand consolidation slug, and may be, for example, ammonium chloride.
Preferably, the pretreatment slug is an aqueous solution comprising 0.5 wt% to 1.5 wt% of an anti-swelling sand-inhibiting agent, 0.2 wt% of sodium lauryl sulfate and 0.3 wt% of ammonium chloride.
Preferably, the pretreated slug is an aqueous solution comprising 1 wt% of the anti-swelling sand-inhibiting agent, 0.2 wt% of sodium lauryl sulfate and 0.3 wt% of ammonium chloride.
Preferably, the anti-swelling sand-suppressing agent is a cationic polymer SW-91, available from Shandong Weifang Tianyang chemical Co., Ltd.
The foamable resin sand consolidation agent can be an existing foamable resin curing agent, and a foamable cementing agent for bonding sand grains in the foamable resin sand consolidation agent can be foamed under the action of a foaming agent, and in practical application, the foamable resin sand consolidation agent in the prior art can be selected according to specific conditions of a stratum according to needs, for example, for a low-temperature stratum at 30-90 ℃, a low-density foam resin sand control agent disclosed in patent CN106634920A can be selected, and correspondingly, for a high-temperature stratum, a sand consolidation agent suitable for high-temperature consolidation can be selected.
The foamable resin sand consolidation agent and the nitrogen in the sand consolidation slug can form a low-density foamed resin sand consolidation system, can be uniformly injected into a sand production position, and after contacting with formation sand, the resin consolidates loose sand grains, and the gas is used as a pore-expanding agent, so that the good permeability after sand consolidation is ensured. In order to further improve the foam stability and sand consolidation effect of the foamed resin sand consolidation system, preferably, in the step (2), the foamable resin sand consolidation agent further comprises a foam stabilizer and a silane coupling agent.
In order to further improve the sand consolidation effect of the foamable resin sand consolidation agent, preferably, the foamable resin sand consolidation agent mainly comprises water and the following raw materials in percentage by weight: 15 to 60 percent of cementing agent which can be foamed and used for bonding sand grains, 0.2 to 0.6 percent of foaming agent, 0.03 to 0.3 percent of curing agent, 0.5 to 1.5 percent of foam stabilizer and 0.1 to 0.5 percent of silane coupling agent; said foamableThe cementing agent used for bonding sand grains is one or more than two of urea-formaldehyde resin, water-soluble phenolic resin, melamine formaldehyde resin and compound phenolic resin, the foaming agent is one or more than two of α -olefin sodium sulfonate, fatty alcohol ether sodium sulfate, lauryl sodium sulfate, octyl phenol polyoxyethylene ether, alkyl glucoside, organic silicon and fatty alcohol, the curing agent is one or more than two of polyvinyl acetate, ammonium dihydrogen phosphate, aluminum chloride, citric acid, ammonium chloride and urea, and the foam stabilizer is carboxyl cellulose, sodium fluoborate, polyvinyl alcohol, polyethylene glycol, sodium-soil solid-phase particles and nano SiO2One or more than two of sodium polyacrylate; the silane coupling agent is one or more than two of gamma-aminopropyl triethoxysilane, gamma-glycidoxypropyl trimethoxysilane and gamma-methacryloxypropyl trimethoxysilane. The sand consolidation agent and nitrogen are injected simultaneously to form low-density foam, and the existence of the nitrogen is favorable for the sand consolidation agent to form a pore channel at a sand outlet position, so that higher permeability is ensured.
Preferably, the foamable binder for binding sand grains is melamine formaldehyde resin; the foaming agent is sodium dodecyl sulfate; the curing agent is ammonium chloride; the foam stabilizer is carboxyl cellulose; the silane coupling agent is gamma-aminopropyl triethoxysilane.
α -olefin sodium sulfonate is called AOS for short, fatty alcohol ether sodium sulfate is called AES for short, sodium dodecyl sulfate is called SDS for short, octyl phenol polyoxyethylene ether is called OP-10 for short, alkyl glycoside is called APG0810 for short, carboxyl cellulose is called CMC for short, gamma-aminopropyl triethoxysilane is called KH-550 for short, gamma-glycidoxypropyl trimethoxysilane is called KH-560 for short, and gamma-methacryloxypropyl trimethoxysilane is called KH-570 for short.
Preferably, the foamable resin sand consolidation agent mainly comprises water and the following raw materials in percentage by weight: 40% of foaming cementing agent for bonding sand grains, 0.5% of foaming agent, 0.1% of curing agent, 1.0% of foam stabilizer and 0.2% of silane coupling agent.
Preferably, the foamable resin sand consolidation agent mainly comprises water and the following raw materials in percentage by weight: 40 percent of melamine formaldehyde resin, 0.5 percent of sodium dodecyl sulfate, 0.1 percent of ammonium chloride, 1.0 percent of carboxymethyl cellulose and KH-5500.2 percent of silane coupling agent.
In order to ensure that the foamable resin sand consolidation agent is fully foamed, and ensure that the sand consolidation agent can form a pore channel when the sand consolidation layer is consolidated, and ensure the permeability, in step (2), preferably, the volume ratio of the foamable resin sand consolidation agent to nitrogen in the sand consolidation slug is 1: 80-200.
It can be understood that the foamable resin sand consolidation agent needs to be prepared before being injected into a sand production layer, and the liquid can be prepared by adopting a method which is conventional in the field as long as the sand consolidation agent can be ensured to be solidified at the sand production layer, preferably, the foamable resin sand consolidation agent is prepared by injecting clear water into a ① liquid preparation pool, preparing a nitrogen vehicle and connecting a pipeline, adding ② amino resin powder and fully stirring uniformly to form a uniform dispersion system which does not have fish eyes and undissolved small blocks, spraying (or slowly spreading) CMC during the stirring process by ③ and continuously stirring uniformly to fully dissolve the CMC while not stirring, wherein the no fish eyes are required, adding ④ and SDS and fully stirring uniformly, adding ⑤ and KH-550 and stirring uniformly, adding ⑥ ammonium chloride and stirring uniformly, starting a nitrogen vehicle and a profile control pump by ⑦, and simultaneously pumping the liquid and the nitrogen according to the ratio of 145:1, wherein the liquid pumping speed can be set as 8m3The nitrogen pumping speed of the nitrogen vehicle is 1160 m mark3/h。
The foamable resin sand consolidation agent has the applicable temperature range of 30-90 ℃, the compression strength of a consolidation body of quartz sand with the particle size of 0.4-0.8 mm is more than or equal to 5MPa, the breaking strength is more than or equal to 2MPa, the permeability retention rate is more than or equal to 75 percent, the acid resistance is good (the acid etching weight loss rate of a standard test block is less than or equal to 5 percent), and the mineralization resistance is more than or equal to 10 multiplied by 104mg/L. The sand consolidation process is suitable for the sand control requirements of common vertical wells, long well section horizontal wells, highly deviated wells, side drilling wells and casing deformation wells, and secondary sand control after mechanical sand control failure, and has the advantages of safe and simple construction process and wide application.
The foamable resin sand consolidation agent takes melamine formaldehyde resin as a main material, and a foaming agent, a stabilizing agent, a cross-linking agent and a curing agent are introduced, so that an effective chemical sand consolidation system is formed. The sand consolidation agent system consolidates the stratum sand in situ, effectively inhibits the stratum sand from flowing, has high strength, can keep higher permeability, can effectively treat the sand production problem of a thin layer and a fine powder sand layer, has simple and convenient construction process and high safety factor, is suitable for secondary sand control after mechanical sand control failure and sand control construction of a highly deviated well and a casing change well, and has wide application.
In order to further improve the permeability of the sand consolidation slug and enable the sand consolidation slug to form enough pore channels when being cemented with sand, preferably, in the step (3), the displacement slug is sequentially a nitrogen slug for displacing and reaming the sand consolidation slug and a displacement liquid slug for displacing the sand consolidation slug to a target formation. The nitrogen slug can further ensure that the sand consolidation slug forms enough pore channels, and the permeability after sand consolidation is improved.
The displacement liquid adopted by the displacement liquid slug can be only used for displacing the sand consolidation agent in the shaft into the sand outlet layer, such as water, clear water or sewage. In the displacement slug, N is firstly adopted2And after the replacement and hole expansion, replacing the hole with sewage or clean water to replace the sand consolidation agent in the shaft into the stratum so as to prevent the sand consolidation agent from being consolidated in the shaft. Namely, after the sand consolidation slug is injected, the nitrogen vehicle continues to inject nitrogen. The discharge capacity of the injected nitrogen is injected according to the maximum discharge capacity of the nitrogen vehicle. After the nitrogen injection is finished, the water is changed.
In order to further improve the permeability, the volume ratio of the nitrogen in the nitrogen slug to the nitrogen in the sand consolidation slug under a standard condition is preferably 2-2.5: 1.
Drawings
FIG. 1 shows the sand consolidation effect of the foamable resin sand consolidation agent used for the sand consolidation slug in the construction method of the foamable resin sand consolidation agent for the argillaceous fine silt reservoir of example 2 at different temperatures;
FIG. 2 shows the production parameters before and after the construction of the foamable resin sand consolidation agent for argillaceous fine silt particle reservoirs in example 3.
Detailed Description
The present invention will be further described with reference to the following embodiments.
The specific embodiment of the construction method of the foamable resin sand consolidation agent for the argillaceous fine silt oil reservoir is as follows:
example 1
The foamable resin sand consolidation agent adopted by the sand consolidation slug in the construction method of the foamable resin sand consolidation agent for the argillaceous fine silt oil reservoir in the embodiment has sand consolidation effect on sand grains with different meshes. The foamable resin sand consolidation agent consists of water and the following raw materials in percentage by weight:
40% of melamine formaldehyde resin, 0.5% of Sodium Dodecyl Sulfate (SDS), 1.0% of carboxymethyl cellulose, 0.1% of ammonium chloride and KH-5500.2% of a silane coupling agent; the balance being water.
The results obtained when 25mL of the foamable resin sand fixing agent of this example was used to fix 100g of 20 to 40 mesh, 40 to 60 mesh, 60 to 80 mesh, 80 to 100 mesh, and 100+ mesh quartz sand, respectively, are shown in Table 1, where the initial permeability was stabilized with 0.5% of a sand control agent (cationic polymer SW-91, available from Shandong Weifang Tianyang chemical Co., Ltd.).
TABLE 1 Sand consolidation Performance of the foamable resin sand consolidation agent of example 1 for different mesh sand grains
| Sand diameter/mesh | 20～40 | 40～60 | 60～80 | 80～100 | 100+ | Stratum sand |
| Compressive strength/MPa | 5.23 | 5.65 | 6.28 | 6.91 | 7.74 | 6.18 |
| Flexural strength/MPa | 2.32 | 2.67 | 3.12 | 3.43 | 3.65 | 2.86 |
| Original permeability/. mu.m2 | 3.78 | 2.85 | 0.55 | 0.45 | 0.37 | 0.58 |
| Permeability of consolidation mass/mum2 | 2.84 | 1.68 | 0.24 | 0.17 | 0.11 | 0.18 |
| Permeability retention/% | 75.13 | 58.95 | 43.86 | 38.16 | 29.84 | 30.97 |
As can be seen from table 1, in the foamable resin sand consolidation agent system, the compressive strength of the consolidated core is higher when the number of the consolidated sand grains is larger, that is, the grain size of the sand grains is smaller. This is because the smaller the sand diameter is, the larger the specific surface area is. The more the amount of resin molecules adhered to the surface of the sand grains during the resin solution injection, the greater the strength of the resin after it is cured. Meanwhile, the smaller the sand diameter is, the smaller the gaps among the sand grains are, the pore volume is reduced, and the effective permeability is reduced.
The 20-40 mesh quartz sand consolidation body has the compression strength of 5.23MPa, the breaking strength of 2.3MPa and the permeability of 2.84 mu m2The permeability retention was 75.13%.
The compression strength of the 80-100 mesh quartz sand consolidation body is 6.91MPa, the breaking strength is 3.43MPa, and the permeability is 0.17 mu m2The permeability retention was 38.16%.
For the formation sand, the compressive strength of the consolidation body is 6.18MPa, the breaking strength is 2.86MPa, and the permeability is 0.18 mu m2The permeability retention was 30.97%.
Example 2
The foamable resin sand consolidation agent adopted by the sand consolidation slug in the construction method of the foamable resin sand consolidation agent for the argillaceous fine silt oil reservoir in the embodiment has sand consolidation effect at different temperatures. The foamable resin sand consolidation agent consists of water and the following raw materials in percentage by weight:
40% of melamine formaldehyde resin, 0.5% of Sodium Dodecyl Sulfate (SDS), 1.0% of carboxymethyl cellulose, 0.1% of ammonium chloride and KH-5500.2% of a silane coupling agent; the balance being water.
The experimental conditions were: 25mL of foamable resin sand consolidation agent, and 100g of sand grains with 40-60 meshes are consolidated; the compressive strength of the consolidated core is measured after curing for 12 hours at the temperature of 30-90 ℃, and the obtained result is shown in figure 1.
As can be seen from FIG. 1, the compressive strength of the consolidated body gradually increases with the temperature rise below 45 ℃ and then changes more gradually; when the temperature is higher than 40 ℃, the compressive strength of the consolidation body is higher than 6 MPa; the compressive strength at 35 ℃ is about 5MPa, and the consolidation core strength reaches more than 5MPa within the range of 35-90 ℃, so that the requirement of chemical sand control consolidation strength of a thin oil reservoir is met.
Example 3
The construction method of the foamable resin sand consolidation agent for the argillaceous fine silt reservoir in the embodiment is used for consolidating sand for a reservoir of a certain oil well.
The oil well is a silty-fine sand oil reservoir, and the permeability is low (0.51 mu m)2) The mud content of a production formation is 6.55%, the porosity is 32.75%, the actual injection well section is 1436.4-1439.2 m, and the thickness is 2.8 m. The well has serious sand production, two blockage removal and sand control measures are implemented successively after the sealing of channeling, but the effect is not ideal, and the expected geological yield is not reached. And analyzing the blockage of the near-wellbore zone of the stratum or the sand prevention sand filtering pipe by combining the condition that the sand-washing return product is fine silt and small blocks of congelation similar to the plugging agent, so that the seepage capability is poor. Aiming at the sand production characteristics of the fine sand low-temperature thin oil reservoir, the construction method of the foamable resin sand consolidation agent for the argillaceous fine sand reservoir is utilized to consolidate sand. High-strength sand consolidation is carried out on the near-wellbore area to form an effective sand blocking barrier, so that fine silt is prevented from blocking a sand control pipe, the sand control effect is improved, and the sand control validity period is prolonged. The construction method of the foamable resin sand consolidation agent for the argillaceous fine silt oil reservoir comprises the following steps:
(1) first slug-purge slug, injecting into the wellbore a first slug: hot water of 80 deg.C, the injection amount is 20m3。
(2) A second slug, a pretreatment slug, which is an aqueous solution comprising 1.0 wt% of an anti-swelling sand-suppressing agent, 0.2 wt% of sodium dodecyl sulfate SDS and 0.3 wt% of ammonium chloride, injected in an amount of 20m3。
Pretreatment and material preparation: 200kg of anti-swelling sand-inhibiting agent and 40kg of sand-inhibiting agentSDS, 60kg ammonium chloride, 20m3And (4) clear water.
The anti-swelling sand-inhibiting agent is a cationic polymer SW-91 and is purchased from Shandong Weifang Tianyang chemical Co.
Formulation injection procedure (at 10 m)310m for the liquid preparation pool3Liquid as an example): 100kg of the anti-swelling sand-inhibiting agent, 20kg of SDS and 30kg of ammonium chloride are added to 10m of the liquid preparation pool3Stirring in clear water, and then stirring for 9m3The displacement of/h is injected into the formation.
(3) And a third slug, namely a sand consolidation slug, wherein the foamable resin sand consolidation agent is an amino resin foam sand consolidation system and consists of the following raw materials in percentage by weight: 58.95% of clear water, 39.3% of amino resin (melamine formaldehyde resin) powder, 0.05% of curing agent (ammonium chloride), 0.5% of foaming agent (SDS), 1% of foam stabilizer (CMC), 0.2% of coupling agent (KH-550), and the injection amount is 12m3。
Preparing a foamable resin sand consolidation agent: 4725kg of amino resin powder, 120kg of CMC, 60kg of SDS, 25kg of KH-550, 6kg of ammonium chloride, 7m3And (4) clear water.
The injection process was formulated (to be at 10 m)3Preparation in the solution preparation tank for example) ① preparation tank is filled with 7m3The method comprises the steps of preparing clear water, preparing a nitrogen vehicle, connecting pipelines, ② adding 4725kg of amino resin powder, sufficiently and uniformly stirring to form a uniform dispersion system, requiring no fish eyes and no undissolved small blocks, ③ adding 120kg of CMC (sodium carboxymethyl cellulose) in a spraying mode (or slowly spreading mode) in the stirring process, continuously and uniformly stirring to fully dissolve the CMC, requiring no fish eyes, ④ adding 60kg of SDS, sufficiently and uniformly stirring, ⑤ adding 25kg of KH-550, uniformly stirring, ⑥ adding 6kg of ammonium chloride, uniformly stirring, ⑦ starting the nitrogen vehicle and a profile control pump, simultaneously pumping liquid and nitrogen into the stratum according to the ratio of 145:1 of gas to liquid, and setting the liquid pumping speed to be 8m3The nitrogen pumping speed of the nitrogen vehicle is 1160 m mark3/h。
It should be noted that the viscosity of the amino resin gradually increases with time after it is exposed to water. In particular, the viscosity increased gradually after the addition of the curing agent ammonium chloride. Therefore, the formulation injection process is required to be rapid and uninterrupted.
(4) And the fourth section plug-displacement section plug is a nitrogen section plug for displacing and expanding the sand consolidation section plug and a clear water section plug for displacing the sand consolidation section plug to the target stratum. N is a radical of2Volume under standard conditions is 4000m3(ii) a The clear water volume is 4.8m3。
Preparing and injecting: and after the third section plug liquid system is injected, the injection liquid pump is stopped. The nitrogen car continues to inject nitrogen. The discharge capacity of the injected nitrogen is injected according to the maximum discharge capacity of a nitrogen vehicle, and the injection quantity is 4000 standard meters3. After the nitrogen injection is finished, clean water is injected for 9m3Per h velocity injection 4.8m3。
After the construction is finished, closing the well and waiting for setting for 6 days.
The production parameters before and after sand consolidation for a certain oil well reservoir in the construction method using the foamable resin sand consolidation agent for a argillaceous fine silt reservoir of the present embodiment are shown in table 2 and fig. 2.
TABLE 2 production parameters before and after construction method of foamable resin sand consolidation agent for argillaceous fine silt reservoir
| Liquid (m) produced in daily life3) | Daily oil (t) | Water content (%) | |
| Before taking measures | 1.4 | 0.3 | 79 |
| After taking measures | 4.2 | 3.2 | 65.4 |
As can be seen from table 2 and fig. 2, after the construction method of the foamable resin sand consolidation agent for the argillaceous fine silt reservoir of the present embodiment is used for construction, the initial production state of the well is good, the sand production at the later stage is serious, the operations such as mechanical sand control and the like (the precision of the sand filter pipe is 0.15mm) are sequentially performed for many times in 18-22 days of 4 months in 2017, 2017.7.13-8.14, 2017.9.8-9.13 and 2017.9.30-10.13 respectively, the effective period is short, the liquid production rate is reduced rapidly in about 20 days generally, and the mechanical sand control effect is not ideal.
The well is opened for production in 11/19/2017, and has been produced for 201/6/13/2018, and accumulated production liquid 2847.9m3Cumulative oil production 633.7t, average daily yield 14.2m3And the average daily oil yield is 3.2t, and a better effect is achieved.
By adopting the combination of the slugs, the effects of sand cleaning, pre-adsorption, cementing and sand consolidation, reaming and permeability increasing and the like are realized, the uniform injection and high-strength sand consolidation are realized, and the sand prevention effect and benefit are ensured. The invention can meet the sand control requirements of long well section horizontal wells, highly deviated wells, side drilling wells and casing deformation wells, and secondary sand control after mechanical sand control, and has safe and simple construction process and wide application.
The above description is only a preferred embodiment of the present application, and not intended to limit the present application, the scope of the present application is defined by the appended claims, and all changes in equivalent structure made by using the contents of the specification and the drawings of the present application should be considered as being included in the scope of the present application.
Claims (10)
1. A construction method of a foamable resin sand consolidation agent for a argillaceous fine silt oil reservoir is characterized by comprising the following steps:
(1) injecting a pretreatment slug into the sand producing layer; the pretreatment slug is an aqueous solution comprising an anti-swelling sand-inhibiting agent;
(2) simultaneously injecting foamable resin sand consolidation agent and nitrogen into the sand production position to form a sand consolidation slug; the foamable resin sand setting agent comprises a foamable cementing agent, a foaming agent and a curing agent for bonding sand grains;
(3) and then injected to displace the slug.
2. The construction method of the foamable resin sand consolidation agent for the argillaceous fine silt deposit according to claim 1, wherein in the step (1), the pretreatment slug further comprises a curing agent; the mass fraction of the curing agent in the aqueous solution is 0.2-0.4%.
3. The method for constructing the foamable resin sand consolidation agent for argillaceous fine silt reservoirs according to claim 1, wherein in the step (2), the foamable resin sand consolidation agent further comprises a foam stabilizer and a silane coupling agent.
4. The construction method of the foamable resin sand consolidation agent for the argillaceous fine silt oil deposit according to claim 3, wherein the foamable resin sand consolidation agent mainly comprises water and the following raw materials in percentage by weight:
15 to 60 percent of cementing agent which can be foamed and used for bonding sand grains, 0.2 to 0.6 percent of foaming agent, 0.03 to 0.3 percent of curing agent, 0.5 to 1.5 percent of foam stabilizer and 0.1 to 0.5 percent of silane coupling agent;
the foaming cementing agent for bonding sand grains is one or more than two of urea-formaldehyde resin, water-soluble phenolic resin, melamine formaldehyde resin and compound phenolic resin;
the foaming agent is one or more than two of α -olefin sodium sulfonate, fatty alcohol ether sodium sulfate, lauryl sodium sulfate, octyl phenol polyoxyethylene ether, alkyl glycoside, organic silicon and fatty alcohol;
the curing agent is one or more than two of polyvinyl acetate, ammonium dihydrogen phosphate, aluminum chloride, citric acid, ammonium chloride and urea;
the foam stabilizer is carboxyl cellulose, sodium fluoborate, polyvinyl alcohol, polyethylene glycol and sodiumSoil solid phase particle, nano SiO2One or more than two of sodium polyacrylate;
the silane coupling agent is one or more than two of gamma-aminopropyl triethoxysilane, gamma-glycidoxypropyl trimethoxysilane and gamma-methacryloxypropyl trimethoxysilane.
5. The construction method of the foamable resin sand consolidation agent for the argillaceous fine silt deposit according to claim 1, wherein in the step (2), the volume ratio of the foamable resin sand consolidation agent to nitrogen in the sand consolidation slug under a standard condition is 1: 80-200.
6. The method for constructing a foamable resin sand consolidating agent for a argillaceous fine silt reservoir according to claim 1, wherein in the step (3), the displacement slug is a nitrogen slug for displacing and reaming the sand consolidating slug and a displacement liquid slug for displacing the sand consolidating slug to a target formation in sequence.
7. The construction method of the foamable resin sand consolidation agent for the argillaceous fine silt oil reservoir according to claim 6, wherein the volume ratio of nitrogen in the nitrogen slug to nitrogen in the sand consolidation slug under a standard condition is 2-2.5: 1.
8. The construction method of the foamable resin sand consolidation agent for the argillaceous fine silt deposit according to any one of claims 1 to 7, wherein in the step (1), before the pretreatment slug is injected into the sand production horizon, a cleaning slug is firstly injected into the wellbore, and the cleaning slug is hot water at the temperature of 70-90 ℃.
9. The construction method of the foamable resin sand consolidation agent for argillaceous fine silt reservoirs according to any one of claims 1 to 7, wherein in the step (1), the mass fraction of the anti-swelling sand-inhibiting agent in the aqueous solution is 0.5% to 1.5%.
10. The method for constructing a foamable resin sand consolidation agent for a argillaceous fine silt deposit according to any one of claims 1 to 7, wherein in the step (1), the pretreatment plug further comprises a surfactant.
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| CN111577215A (en) * | 2020-06-16 | 2020-08-25 | 青岛大地新能源技术研究院 | Sand control system combining high molecules and low-molecular polymers for fine silt |
| CN111690399A (en) * | 2020-04-27 | 2020-09-22 | 北京大德广源石油技术服务有限公司 | Sand control agent for fracturing and use method thereof |
| CN112358860A (en) * | 2020-11-17 | 2021-02-12 | 中国石油大学(华东) | Active component and system of resin foam type channeling-blocking and plugging-adjusting agent, and preparation method and application thereof |
| CN112521926A (en) * | 2020-05-06 | 2021-03-19 | 中国石油天然气股份有限公司 | Water-based compound type foam resin sand prevention system, preparation method and application thereof |
| CN112920786A (en) * | 2021-02-01 | 2021-06-08 | 成都理工大学 | Composite sand control agent with high permeability retention rate |
| CN114315937A (en) * | 2022-01-13 | 2022-04-12 | 陕西科技大学 | Biomass nanometer permeation enhancer for pressure flooding and fracturing and preparation method and application thereof |
| CN115304784A (en) * | 2022-09-29 | 2022-11-08 | 北京平储能源技术有限公司 | Boron nitride modified phenolic resin sand control agent and preparation method and application thereof |
| CN117551440A (en) * | 2024-01-10 | 2024-02-13 | 东营煜煌能源技术有限公司 | Foamed resin sand-fixing agent and preparation method thereof |
| CN117844464A (en) * | 2024-03-07 | 2024-04-09 | 东营区四通化工有限责任公司 | High-permeability resin sand-fixing agent for fracturing and manufacturing method thereof |
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| CN111690399A (en) * | 2020-04-27 | 2020-09-22 | 北京大德广源石油技术服务有限公司 | Sand control agent for fracturing and use method thereof |
| CN111690399B (en) * | 2020-04-27 | 2021-09-07 | 北京大德广源石油技术服务有限公司 | Sand control agent for fracturing and use method thereof |
| CN112521926A (en) * | 2020-05-06 | 2021-03-19 | 中国石油天然气股份有限公司 | Water-based compound type foam resin sand prevention system, preparation method and application thereof |
| CN111577215B (en) * | 2020-06-16 | 2022-04-05 | 青岛大地新能源技术研究院 | Sand control system combining high molecules and low-molecular polymers for fine silt |
| CN111577215A (en) * | 2020-06-16 | 2020-08-25 | 青岛大地新能源技术研究院 | Sand control system combining high molecules and low-molecular polymers for fine silt |
| CN112358860A (en) * | 2020-11-17 | 2021-02-12 | 中国石油大学(华东) | Active component and system of resin foam type channeling-blocking and plugging-adjusting agent, and preparation method and application thereof |
| CN112920786A (en) * | 2021-02-01 | 2021-06-08 | 成都理工大学 | Composite sand control agent with high permeability retention rate |
| CN114315937A (en) * | 2022-01-13 | 2022-04-12 | 陕西科技大学 | Biomass nanometer permeation enhancer for pressure flooding and fracturing and preparation method and application thereof |
| CN114315937B (en) * | 2022-01-13 | 2024-08-09 | 甘肃智仑新材料科技有限公司 | Biomass nanometer permeability enhancer for pressure flooding and fracturing and preparation method and application thereof |
| CN115304784A (en) * | 2022-09-29 | 2022-11-08 | 北京平储能源技术有限公司 | Boron nitride modified phenolic resin sand control agent and preparation method and application thereof |
| CN117551440A (en) * | 2024-01-10 | 2024-02-13 | 东营煜煌能源技术有限公司 | Foamed resin sand-fixing agent and preparation method thereof |
| CN117551440B (en) * | 2024-01-10 | 2024-03-26 | 东营煜煌能源技术有限公司 | Foamed resin sand-fixing agent and preparation method thereof |
| CN117844464A (en) * | 2024-03-07 | 2024-04-09 | 东营区四通化工有限责任公司 | High-permeability resin sand-fixing agent for fracturing and manufacturing method thereof |
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