CN112111258A - Water-lock injury blocking remover, use method thereof and water-lock injury acidizing fluid - Google Patents
Water-lock injury blocking remover, use method thereof and water-lock injury acidizing fluid Download PDFInfo
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- CN112111258A CN112111258A CN201910533695.2A CN201910533695A CN112111258A CN 112111258 A CN112111258 A CN 112111258A CN 201910533695 A CN201910533695 A CN 201910533695A CN 112111258 A CN112111258 A CN 112111258A
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- Prior art keywords
- water
- acid
- blocking remover
- lock
- injury
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- 230000006378 damage Effects 0.000 title claims abstract description 70
- 230000000903 blocking effect Effects 0.000 title claims abstract description 57
- 239000012530 fluid Substances 0.000 title claims abstract description 44
- 208000027418 Wounds and injury Diseases 0.000 title claims abstract description 36
- 208000014674 injury Diseases 0.000 title claims abstract description 36
- 238000000034 method Methods 0.000 title claims abstract description 28
- 239000002253 acid Substances 0.000 claims abstract description 95
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 61
- 230000007797 corrosion Effects 0.000 claims abstract description 44
- 238000005260 corrosion Methods 0.000 claims abstract description 44
- 239000007788 liquid Substances 0.000 claims abstract description 44
- 239000000654 additive Substances 0.000 claims abstract description 34
- 230000000996 additive effect Effects 0.000 claims abstract description 32
- 239000003112 inhibitor Substances 0.000 claims abstract description 27
- 239000004927 clay Substances 0.000 claims abstract description 26
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims abstract description 25
- 239000008139 complexing agent Substances 0.000 claims abstract description 23
- 239000003381 stabilizer Substances 0.000 claims abstract description 21
- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonia chloride Chemical compound [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 claims abstract description 18
- 239000003340 retarding agent Substances 0.000 claims abstract description 18
- 230000000979 retarding effect Effects 0.000 claims abstract description 18
- 239000002904 solvent Substances 0.000 claims abstract description 18
- 239000003093 cationic surfactant Substances 0.000 claims abstract description 14
- 239000002736 nonionic surfactant Substances 0.000 claims abstract description 12
- 235000019270 ammonium chloride Nutrition 0.000 claims abstract description 9
- 239000004094 surface-active agent Substances 0.000 claims description 27
- LZZYPRNAOMGNLH-UHFFFAOYSA-M Cetrimonium bromide Chemical compound [Br-].CCCCCCCCCCCCCCCC[N+](C)(C)C LZZYPRNAOMGNLH-UHFFFAOYSA-M 0.000 claims description 25
- NBIIXXVUZAFLBC-UHFFFAOYSA-N Phosphoric acid Chemical compound OP(O)(O)=O NBIIXXVUZAFLBC-UHFFFAOYSA-N 0.000 claims description 22
- 229940051841 polyoxyethylene ether Drugs 0.000 claims description 18
- 229920000056 polyoxyethylene ether Polymers 0.000 claims description 18
- HRPVXLWXLXDGHG-UHFFFAOYSA-N Acrylamide Chemical compound NC(=O)C=C HRPVXLWXLXDGHG-UHFFFAOYSA-N 0.000 claims description 17
- 229920001577 copolymer Polymers 0.000 claims description 17
- NBVXSUQYWXRMNV-UHFFFAOYSA-N fluoromethane Chemical compound FC NBVXSUQYWXRMNV-UHFFFAOYSA-N 0.000 claims description 16
- KWIUHFFTVRNATP-UHFFFAOYSA-N Betaine Natural products C[N+](C)(C)CC([O-])=O KWIUHFFTVRNATP-UHFFFAOYSA-N 0.000 claims description 12
- KWIUHFFTVRNATP-UHFFFAOYSA-O N,N,N-trimethylglycinium Chemical compound C[N+](C)(C)CC(O)=O KWIUHFFTVRNATP-UHFFFAOYSA-O 0.000 claims description 12
- 229960003237 betaine Drugs 0.000 claims description 12
- 150000003242 quaternary ammonium salts Chemical class 0.000 claims description 12
- 229910000147 aluminium phosphate Inorganic materials 0.000 claims description 11
- 229940090960 diethylenetriamine pentamethylene phosphonic acid Drugs 0.000 claims description 11
- DUYCTCQXNHFCSJ-UHFFFAOYSA-N dtpmp Chemical compound OP(=O)(O)CN(CP(O)(O)=O)CCN(CP(O)(=O)O)CCN(CP(O)(O)=O)CP(O)(O)=O DUYCTCQXNHFCSJ-UHFFFAOYSA-N 0.000 claims description 11
- 125000002091 cationic group Chemical group 0.000 claims description 10
- 239000000178 monomer Substances 0.000 claims description 10
- 238000006243 chemical reaction Methods 0.000 claims description 9
- LOGBRYZYTBQBTB-UHFFFAOYSA-N butane-1,2,4-tricarboxylic acid Chemical compound OC(=O)CCC(C(O)=O)CC(O)=O LOGBRYZYTBQBTB-UHFFFAOYSA-N 0.000 claims description 5
- 238000005406 washing Methods 0.000 claims description 4
- 229920000536 2-Acrylamido-2-methylpropane sulfonic acid Polymers 0.000 claims description 3
- XHZPRMZZQOIPDS-UHFFFAOYSA-N 2-Methyl-2-[(1-oxo-2-propenyl)amino]-1-propanesulfonic acid Chemical compound OS(=O)(=O)CC(C)(C)NC(=O)C=C XHZPRMZZQOIPDS-UHFFFAOYSA-N 0.000 claims description 3
- 239000002131 composite material Substances 0.000 claims description 2
- 239000004576 sand Substances 0.000 claims description 2
- 230000020477 pH reduction Effects 0.000 abstract description 5
- 239000000126 substance Substances 0.000 abstract description 5
- QGZKDVFQNNGYKY-UHFFFAOYSA-N Ammonia Chemical compound N QGZKDVFQNNGYKY-UHFFFAOYSA-N 0.000 abstract 1
- 239000003921 oil Substances 0.000 description 26
- 239000002585 base Substances 0.000 description 25
- -1 iron ions Chemical class 0.000 description 18
- 239000011435 rock Substances 0.000 description 16
- 230000005764 inhibitory process Effects 0.000 description 15
- 230000002829 reductive effect Effects 0.000 description 14
- 238000010276 construction Methods 0.000 description 13
- 230000001965 increasing effect Effects 0.000 description 13
- 230000000694 effects Effects 0.000 description 12
- 238000001556 precipitation Methods 0.000 description 10
- 238000012360 testing method Methods 0.000 description 10
- 230000035699 permeability Effects 0.000 description 9
- 230000008569 process Effects 0.000 description 9
- 238000002347 injection Methods 0.000 description 8
- 239000007924 injection Substances 0.000 description 8
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 7
- 239000001257 hydrogen Substances 0.000 description 7
- 229910052739 hydrogen Inorganic materials 0.000 description 7
- 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 6
- POAOYUHQDCAZBD-UHFFFAOYSA-N 2-butoxyethanol Chemical compound CCCCOCCO POAOYUHQDCAZBD-UHFFFAOYSA-N 0.000 description 6
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 description 6
- 229910052742 iron Inorganic materials 0.000 description 6
- 239000000843 powder Substances 0.000 description 6
- BDERNNFJNOPAEC-UHFFFAOYSA-N propan-1-ol Chemical compound CCCO BDERNNFJNOPAEC-UHFFFAOYSA-N 0.000 description 6
- 239000010779 crude oil Substances 0.000 description 5
- 239000006185 dispersion Substances 0.000 description 5
- KWOLFJPFCHCOCG-UHFFFAOYSA-N Acetophenone Chemical compound CC(=O)C1=CC=CC=C1 KWOLFJPFCHCOCG-UHFFFAOYSA-N 0.000 description 4
- VTYYLEPIZMXCLO-UHFFFAOYSA-L Calcium carbonate Chemical compound [Ca+2].[O-]C([O-])=O VTYYLEPIZMXCLO-UHFFFAOYSA-L 0.000 description 4
- KRHYYFGTRYWZRS-UHFFFAOYSA-N Fluorane Chemical compound F KRHYYFGTRYWZRS-UHFFFAOYSA-N 0.000 description 4
- KFZMGEQAYNKOFK-UHFFFAOYSA-N Isopropanol Chemical compound CC(C)O KFZMGEQAYNKOFK-UHFFFAOYSA-N 0.000 description 4
- 239000002202 Polyethylene glycol Substances 0.000 description 4
- HUMNYLRZRPPJDN-UHFFFAOYSA-N benzaldehyde Chemical compound O=CC1=CC=CC=C1 HUMNYLRZRPPJDN-UHFFFAOYSA-N 0.000 description 4
- 230000033558 biomineral tissue development Effects 0.000 description 4
- 239000003795 chemical substances by application Substances 0.000 description 4
- 238000011161 development Methods 0.000 description 4
- 230000018109 developmental process Effects 0.000 description 4
- 238000004519 manufacturing process Methods 0.000 description 4
- 239000003129 oil well Substances 0.000 description 4
- 229920001223 polyethylene glycol Polymers 0.000 description 4
- QTBSBXVTEAMEQO-UHFFFAOYSA-N Acetic acid Chemical compound CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 description 3
- 239000003513 alkali Substances 0.000 description 3
- 150000001875 compounds Chemical class 0.000 description 3
- 238000006073 displacement reaction Methods 0.000 description 3
- 238000001035 drying Methods 0.000 description 3
- 239000007789 gas Substances 0.000 description 3
- 239000012535 impurity Substances 0.000 description 3
- 239000000203 mixture Substances 0.000 description 3
- 239000002245 particle Substances 0.000 description 3
- 238000011056 performance test Methods 0.000 description 3
- 239000012071 phase Substances 0.000 description 3
- 239000000047 product Substances 0.000 description 3
- 230000036632 reaction speed Effects 0.000 description 3
- 239000002455 scale inhibitor Substances 0.000 description 3
- 239000000243 solution Substances 0.000 description 3
- 230000002195 synergetic effect Effects 0.000 description 3
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 description 2
- AFBPFSWMIHJQDM-UHFFFAOYSA-N N-methylaniline Chemical compound CNC1=CC=CC=C1 AFBPFSWMIHJQDM-UHFFFAOYSA-N 0.000 description 2
- 229910019142 PO4 Inorganic materials 0.000 description 2
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical compound [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 description 2
- 239000004480 active ingredient Substances 0.000 description 2
- 239000013543 active substance Substances 0.000 description 2
- 125000002252 acyl group Chemical group 0.000 description 2
- 125000000217 alkyl group Chemical group 0.000 description 2
- 150000001412 amines Chemical class 0.000 description 2
- 125000003118 aryl group Chemical group 0.000 description 2
- 239000011575 calcium Substances 0.000 description 2
- 229910052791 calcium Inorganic materials 0.000 description 2
- 229910000019 calcium carbonate Inorganic materials 0.000 description 2
- 239000001506 calcium phosphate Substances 0.000 description 2
- 229910000389 calcium phosphate Inorganic materials 0.000 description 2
- 235000011010 calcium phosphates Nutrition 0.000 description 2
- 125000002843 carboxylic acid group Chemical group 0.000 description 2
- 238000004581 coalescence Methods 0.000 description 2
- 238000010668 complexation reaction Methods 0.000 description 2
- 238000000354 decomposition reaction Methods 0.000 description 2
- GQOKIYDTHHZSCJ-UHFFFAOYSA-M dimethyl-bis(prop-2-enyl)azanium;chloride Chemical compound [Cl-].C=CC[N+](C)(C)CC=C GQOKIYDTHHZSCJ-UHFFFAOYSA-M 0.000 description 2
- 238000004090 dissolution Methods 0.000 description 2
- 238000005553 drilling Methods 0.000 description 2
- 239000003814 drug Substances 0.000 description 2
- 230000000668 effect on calcium Effects 0.000 description 2
- 239000000839 emulsion Substances 0.000 description 2
- 230000003628 erosive effect Effects 0.000 description 2
- 238000011156 evaluation Methods 0.000 description 2
- 238000002474 experimental method Methods 0.000 description 2
- 230000007062 hydrolysis Effects 0.000 description 2
- 238000006460 hydrolysis reaction Methods 0.000 description 2
- 125000002887 hydroxy group Chemical group [H]O* 0.000 description 2
- 230000002401 inhibitory effect Effects 0.000 description 2
- 235000014413 iron hydroxide Nutrition 0.000 description 2
- NCNCGGDMXMBVIA-UHFFFAOYSA-L iron(ii) hydroxide Chemical compound [OH-].[OH-].[Fe+2] NCNCGGDMXMBVIA-UHFFFAOYSA-L 0.000 description 2
- 229910021645 metal ion Inorganic materials 0.000 description 2
- 230000005012 migration Effects 0.000 description 2
- 238000013508 migration Methods 0.000 description 2
- QNGNSVIICDLXHT-UHFFFAOYSA-N para-ethylbenzaldehyde Natural products CCC1=CC=C(C=O)C=C1 QNGNSVIICDLXHT-UHFFFAOYSA-N 0.000 description 2
- DTUQWGWMVIHBKE-UHFFFAOYSA-N phenylacetaldehyde Chemical compound O=CCC1=CC=CC=C1 DTUQWGWMVIHBKE-UHFFFAOYSA-N 0.000 description 2
- NBIIXXVUZAFLBC-UHFFFAOYSA-K phosphate Chemical compound [O-]P([O-])([O-])=O NBIIXXVUZAFLBC-UHFFFAOYSA-K 0.000 description 2
- 239000010452 phosphate Substances 0.000 description 2
- UEZVMMHDMIWARA-UHFFFAOYSA-M phosphonate Chemical compound [O-]P(=O)=O UEZVMMHDMIWARA-UHFFFAOYSA-M 0.000 description 2
- 239000011148 porous material Substances 0.000 description 2
- 239000002244 precipitate Substances 0.000 description 2
- 238000011084 recovery Methods 0.000 description 2
- 150000003839 salts Chemical class 0.000 description 2
- 238000000926 separation method Methods 0.000 description 2
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N silicon dioxide Inorganic materials O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 2
- 125000000542 sulfonic acid group Chemical group 0.000 description 2
- UMGDCJDMYOKAJW-UHFFFAOYSA-N thiourea Chemical compound NC(N)=S UMGDCJDMYOKAJW-UHFFFAOYSA-N 0.000 description 2
- QORWJWZARLRLPR-UHFFFAOYSA-H tricalcium bis(phosphate) Chemical compound [Ca+2].[Ca+2].[Ca+2].[O-]P([O-])([O-])=O.[O-]P([O-])([O-])=O QORWJWZARLRLPR-UHFFFAOYSA-H 0.000 description 2
- 238000005303 weighing Methods 0.000 description 2
- PSBDWGZCVUAZQS-UHFFFAOYSA-N (dimethylsulfonio)acetate Chemical compound C[S+](C)CC([O-])=O PSBDWGZCVUAZQS-UHFFFAOYSA-N 0.000 description 1
- JKNCOURZONDCGV-UHFFFAOYSA-N 2-(dimethylamino)ethyl 2-methylprop-2-enoate Chemical group CN(C)CCOC(=O)C(C)=C JKNCOURZONDCGV-UHFFFAOYSA-N 0.000 description 1
- WBEHKXQILJKFIN-UHFFFAOYSA-N 2-amino-2-methyltetradecanoic acid Chemical compound CCCCCCCCCCCCC(C)(N)C(O)=O WBEHKXQILJKFIN-UHFFFAOYSA-N 0.000 description 1
- VEXZGXHMUGYJMC-UHFFFAOYSA-M Chloride anion Chemical compound [Cl-] VEXZGXHMUGYJMC-UHFFFAOYSA-M 0.000 description 1
- 229920003171 Poly (ethylene oxide) Polymers 0.000 description 1
- XSQUKJJJFZCRTK-UHFFFAOYSA-N Urea Natural products NC(N)=O XSQUKJJJFZCRTK-UHFFFAOYSA-N 0.000 description 1
- 150000007513 acids Chemical class 0.000 description 1
- 239000000853 adhesive Substances 0.000 description 1
- 230000001070 adhesive effect Effects 0.000 description 1
- 239000012670 alkaline solution Substances 0.000 description 1
- 239000007864 aqueous solution Substances 0.000 description 1
- 239000010426 asphalt Substances 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- FOCAUTSVDIKZOP-UHFFFAOYSA-N chloroacetic acid Chemical compound OC(=O)CCl FOCAUTSVDIKZOP-UHFFFAOYSA-N 0.000 description 1
- 229940106681 chloroacetic acid Drugs 0.000 description 1
- 239000000084 colloidal system Substances 0.000 description 1
- 230000000536 complexating effect Effects 0.000 description 1
- 238000007599 discharging Methods 0.000 description 1
- 239000003792 electrolyte Substances 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 150000004673 fluoride salts Chemical class 0.000 description 1
- 125000001153 fluoro group Chemical class F* 0.000 description 1
- 238000000227 grinding Methods 0.000 description 1
- 238000010438 heat treatment Methods 0.000 description 1
- 150000002431 hydrogen Chemical class 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-M hydroxide Chemical compound [OH-] XLYOFNOQVPJJNP-UHFFFAOYSA-M 0.000 description 1
- 229910052500 inorganic mineral Inorganic materials 0.000 description 1
- 238000005342 ion exchange Methods 0.000 description 1
- 150000002500 ions Chemical class 0.000 description 1
- 239000007791 liquid phase Substances 0.000 description 1
- 239000011159 matrix material Substances 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 239000002207 metabolite Substances 0.000 description 1
- WSFSSNUMVMOOMR-NJFSPNSNSA-N methanone Chemical compound O=[14CH2] WSFSSNUMVMOOMR-NJFSPNSNSA-N 0.000 description 1
- 244000005700 microbiome Species 0.000 description 1
- 239000011707 mineral Substances 0.000 description 1
- 235000010755 mineral Nutrition 0.000 description 1
- 238000002156 mixing Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000003472 neutralizing effect Effects 0.000 description 1
- 239000012188 paraffin wax Substances 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 229940100595 phenylacetaldehyde Drugs 0.000 description 1
- 239000002798 polar solvent Substances 0.000 description 1
- 239000001103 potassium chloride Substances 0.000 description 1
- 235000011164 potassium chloride Nutrition 0.000 description 1
- 239000002994 raw material Substances 0.000 description 1
- 230000035484 reaction time Effects 0.000 description 1
- 238000010992 reflux Methods 0.000 description 1
- 238000007873 sieving Methods 0.000 description 1
- 239000000377 silicon dioxide Substances 0.000 description 1
- 235000019832 sodium triphosphate Nutrition 0.000 description 1
- 239000007790 solid phase Substances 0.000 description 1
- 238000001179 sorption measurement Methods 0.000 description 1
- 230000003068 static effect Effects 0.000 description 1
- 229940117986 sulfobetaine Drugs 0.000 description 1
- 230000008961 swelling Effects 0.000 description 1
- 230000005514 two-phase flow Effects 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
- C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
-
- 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
- C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
- C09K8/528—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/602—Compositions for stimulating production by acting on the underground formation containing surfactants
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/602—Compositions for stimulating production by acting on the underground formation containing surfactants
- C09K8/604—Polymeric surfactants
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/72—Eroding chemicals, e.g. acids
- C09K8/725—Compositions containing polymers
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/72—Eroding chemicals, e.g. acids
- C09K8/74—Eroding chemicals, e.g. acids combined with additives added for specific purposes
-
- 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
- E21B37/00—Methods or apparatus for cleaning boreholes or wells
- E21B37/06—Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting, e.g. eliminating, the deposition of paraffins or like substances
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
-
- 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
-
- 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
- C09K2208/32—Anticorrosion additives
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- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- General Chemical & Material Sciences (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Geochemistry & Mineralogy (AREA)
- Inorganic Chemistry (AREA)
- Detergent Compositions (AREA)
Abstract
The invention relates to a water-lock injury blocking remover, a using method thereof and a water-lock injury acidizing fluid, and belongs to the field of oilfield chemical application. The water-locking damage blocking remover comprises a preposed acid, a main body treatment liquid and a postposition liquid, wherein the preposed acid comprises the following components in percentage by mass: 10-15% of retarding acid, 0.3-1% of corrosion inhibitor, 0.3-0.7% of complexing agent, 0.3-1.7% of clay stabilizer, 0.4-1% of retarding agent, 0.2-0.8% of cleanup additive and the balance of water; the main body treatment liquid comprises the following components in percentage by mass: 20-50% of ethanol, 0.2-1% of nonionic surfactant, 0.5-1.5% of mutual solvent and the balance of water; the post liquid consists of cationic surfactant, ammonium chloride and water. The blocking remover of the invention removes the blocking by the combination of the preposed acid, the main body treatment fluid and the postposition fluid, so that the acidification blocking removal has larger action range and longer action time.
Description
Technical Field
The invention relates to a water-lock injury blocking remover, a using method thereof and a water-lock injury acidizing fluid, and belongs to the field of oilfield chemical application.
Background
By the end of 2000 years, the geological reserve of the low-permeability oil field which has been proved in China is 52.14 multiplied by 108Ton, which accounts for 26.1% of the total proven geological reserves. The low permeability oil field geological reserve which has been used in China is 26.66 multiplied by 108Ton, 25.5% of the total used reserve. With the depth of exploration, low permeability oil fields have become one of the important areas of crude oil production. Therefore, the development of low-permeability oil fields is of great significance to the future development of the petroleum industry in China.
The low permeability reservoir has low natural productivity of an oil well due to compact lithology and large seepage resistance, and generally can obtain high productivity by adopting modification measures such as fracturing, acidification and the like. In the operation process, water lock damage is often caused by incompatible working fluids, untimely backflow of external fluids, blockage of solid-phase particles and the like, and the yield of part of oil wells is greatly reduced and even the oil production capacity is lost. Experiments show that after an external fluid invades into the low-permeability core, the oil phase permeability is seriously damaged, the permeability is reduced by 60-80%, and the flowing pressure is improved by 1-3 times. Reservoir damage caused by the problem of well entry fluid is common in part of low permeability reservoirs. In addition, in the water injection development process of the low-permeability oil and gas field, due to incompatibility of external fluid with reservoir rock minerals, reservoir fluid and the like, existence of metabolites such as suspended substances and microorganisms in water, separation of paraffin, asphalt colloid and the like in crude oil, stratum blockage is often caused, high-pressure underinjection of a water injection well is caused, and crude oil production is influenced. Therefore, corresponding reservoir pollution treatment measures are provided according to the low-permeability oil layer damage mechanism, and the method is very important for the development of the low-permeability oil reservoir.
Among the measures for relieving damage to low-permeability reservoir reservoirs, particularly water-lock damage, which have been reported at present, it is a very important measure to achieve the relief of damage by changing the wettability of the rock surface and reducing the interfacial tension between oil and water phases and the surface tension between gas and liquid phases using a surface active ingredient. However, because the plugging removal of the low-permeability reservoir is carried out only by depending on an active agent system, the reaction speed is slow, the well needs to be closed for 2-3 days for reaction after construction, the operation construction takes long time, and the construction cost is increased; and the temperature resistance of the commonly used surfactant is poor, generally lower than 80 ℃, and the application range is influenced. In order to solve the problems, the Chinese patent application with the application publication number of CN104449619A discloses a water-locking damage blocking remover for downhole operation, which comprises the following components in parts by weight: 30-50 parts of hydrochloric acid, 10-20 parts of erucamidopropyl sulfobetaine, 15-35 parts of ethanol, 5-20 parts of potassium chloride, 10-35 parts of dodecyl amino propionic acid and 2-7 parts of sodium tripolyphosphate; the water lock damage blocking remover for downhole operation uses a large amount of hydrochloric acid, can accelerate the reaction, and simultaneously has certain advantages in the aspects of clay stability and temperature resistance (not more than 100 ℃), but generally, the formation damage of a low-permeability reservoir is not caused by a single factor, the blocking reason and the type are complex, the blocking removal effect of a common active agent system is single, the water lock damage can only be removed, and the oil increasing effect is not obvious after the water lock damage blocking remover is used. Also, for example, chinese patent application with application publication No. CN105733543A discloses a water-lock releasing agent for low water-cut oil wells, which is composed of nano-silica with original particle size of 15-30nm and a water-lock releasing agent composed of ethylene glycol monobutyl ether, and the water-lock releasing agent can eliminate the interface between oil and water in a short time, but is only suitable for low water-cut oil wells when used for releasing water-lock damage, and also has the disadvantage of single purpose of blocking release.
Disclosure of Invention
The invention aims to provide a water-lock damage blocking remover which mainly removes water-lock damage and can remove various types of blockage.
The invention also provides a using method of the water lock injury blocking remover and a water lock injury acidizing fluid.
In order to realize the purposes, the technical scheme adopted by the water-locking injury blocking remover is as follows:
the water-locking injury blocking remover comprises a preposed acid, a main body treatment fluid and a postposition fluid, wherein the preposed acid consists of the following components in percentage by mass: 10-15% of retarding acid, 0.3-1% of corrosion inhibitor, 0.3-0.7% of complexing agent, 0.3-1.7% of clay stabilizer, 0.4-1% of retarding agent, 0.2-0.8% of cleanup additive and the balance of water;
the main body treatment liquid comprises the following components in percentage by mass: 20-50% of ethanol, 0.2-1% of nonionic surfactant, 0.5-1.5% of mutual solvent and the balance of water;
the postposition liquid comprises the following components in percentage by mass: 0.2-0.8% of cationic surfactant, 1-1.5% of ammonium chloride and the balance of water.
The water lock damage blocking remover disclosed by the invention can remove blocking through the combination of the preposed acid, the main body treatment liquid and the postposition liquid, so that water lock damage is mainly removed, and various types of blocking can be removed; and the acidification blockage removal effect range is wider, and the effect time is longer, so that the purpose of increasing the production and injection of the oil and gas well is realized.
In the pre-acid of the water-locking damage blocking remover, the low-damage retarded acid is mainly used for pretreating the stratum to remove mechanical impurities and inorganic blocking in a near-wellbore zone, and meanwhile, the pH value of an acid liquid system is always less than 2 under the stratum condition, so that hydroxide precipitation can be effectively avoided; the corrosion inhibitor in the preposed acid solution can effectively prevent the corrosion of the blocking remover to construction equipment and pipelines; the complexing agent can be complexed with iron ionsReacting to prevent iron ions from generating precipitates; the clay stabilizer can prevent the pollution caused by clay expansion and migration in a reservoir caused by acid liquor; the retarder can be adsorbed on the rock surface to prevent H+The acid rock reaction speed is reduced by contacting with the rock surface; the cleanup additive can reduce the surface tension between the acid liquor and the crude oil, reduce capillary resistance, adjust rock wettability and help the acid liquor to flow back.
In the main treatment fluid of the water-lock damage blocking remover, the mutual solvent can reduce the oil-water interfacial tension and the oil-water flow resistance, and is beneficial to the backflow of residual acid; the ethanol has the functions of dissolving aid and discharging aid, and can enhance the adsorption capacity of the main treatment liquid on the surface of the rock; the synergistic effect between the nonionic surfactant and the mutual solvent can reduce the interfacial tension and improve the wettability of stratum rock, thereby reducing the seepage resistance of oil layer pores.
The postposition liquid is used for displacement, so that the main acid can slowly enter a pore throat of the matrix, and is uniformly diffused, and the effective blockage removal range and depth are increased. The ammonium chloride in the post liquid stabilizes the clay and other particles by means of ion exchange, and prevents the clay from swelling, dispersing and transferring; the cationic surfactant is used for neutralizing the negative charges on the surfaces of the oil droplets, the electrostatic repulsion between the neutralized oil droplets is reduced, the collision and coalescence probability between the oil droplets is increased, the stability of the emulsion is poor, and the purposes of emulsion breaking, coalescence and oil-water separation are achieved.
Compared with the prior art, the water-locking injury blocking remover has the following advantages:
1) the inorganic blockage can be removed, the water lock damage can be removed, and the problem that the oil increase and the injection increase are not obvious due to the narrow application range of the common water lock blocking remover is solved;
2) the adhesive force of a solid-liquid interface is effectively reduced through the compound synergistic effect of a plurality of surfactants;
3) the corrosion is low, and the construction can be carried out by adopting a fixed pipe column, so that the operation cost is saved; the well shut-in time is only 2-6 hours, and the operation occupied time is short;
4) the complex has strong complexation performance, thereby having good scale inhibition capability, effectively inhibiting the product precipitation generated by the reaction of the sandstone and the acid liquor, and further avoiding the occurrence of secondary precipitation.
Preferably, the volume ratio of the pre-acid to the main body treatment liquid to the post-liquid is 3-6: 3-15: 3-13.
Preferably, the retarded acid is at least one of a polyhydroic acid and a phosphoric acid.
The polyhydrogen acid is phosphonate compound, is composed of alkyl, aryl, phosphonate, phosphate, acyl, amine, hydroxyl group and the like, and can react with fluorine salt to generate hydrofluoric acid. The phosphonate compound contains a plurality of hydrogen ions, the hydrogen ions are decomposed under different stoichiometric conditions through multi-stage ionization, and the concentration of the ionized hydrogen ions is always at a lower level, so that the excessive acid concentration is prevented from greatly eroding rocks in a near-wellbore area.
Preferably, the complexing agent is at least one of diethylenetriamine pentamethylene phosphonic acid and 2-phosphonic butane-1, 2, 4-tricarboxylic acid. The diethylenetriamine pentamethylene phosphonic acid can form various stable complexes with various metal ions, has stable chemical properties and is not easy to decompose in strong acid and alkali media; the 2-phosphonic butane-1, 2, 4-tricarboxylic acid is combined with iron ions to form a complex which is soluble in water, and the chance of precipitation of iron hydroxide is reduced.
Preferably, the corrosion inhibitor is at least one of a mannich base quaternary ammonium salt and a bis-mannich base. The Mannich base quaternary ammonium salt used as the corrosion inhibitor has the characteristics of high temperature resistance, stable structure, good compatibility with other acid liquor additives, low cost and obvious corrosion inhibition effect. The bis-Mannich base has the characteristics of good corrosion inhibition performance, good dissolution and dispersion properties, no precipitation, stable corrosion inhibition performance and the like in acid liquor.
Preferably, the clay stabilizer is a copolymer of acrylamide and a cationic monomer, poly (dimethyldiallylammonium chloride) [ (C)8H16NCl)n]At least one of (1). The cationic monomer is dimethylaminoethyl methacrylate (C)8H15NO2) And at least one of polydimethyldiallylammonium chloride.
Preferably, the retarder is a copolymer of acrylamide and 2-acrylamido-2-methylpropanesulfonic acid. Compared with other retarders in the prior art, the retarder has good thermal stability (the decomposition temperature exceeds 200 ℃) and good hydrolysis resistance under the condition of high mineralization degree. Meanwhile, the molecular structure contains carboxylic acid group with scale inhibition and dispersion performance and sulfonic acid group with strong polarity, so that the calcium tolerance can be improved, the scale inhibitor has obvious scale inhibition effect on calcium phosphate, calcium carbonate and the like in water, and the dispersion performance is excellent.
Preferably, the cleanup additive is at least one of cetyl trimethyl ammonium bromide, alkylphenol ethoxylates and betaine type zwitterionic fluorocarbon surfactant. Further preferably, the cleanup additive consists of cetyl trimethyl ammonium bromide, alkylphenol ethoxylates and betaine type zwitterionic fluorocarbon surfactant. The cleanup additive prepared by the three components can greatly reduce the dosage of the surfactant while improving the surface/interface activity, reduce the cost of the medicament, and avoid the difficulty in taking account of the effects of reducing the surface tension and increasing the contact angle of a single surfactant. Further preferably, in the cleanup additive, the mass ratio of the cetyl trimethyl ammonium bromide to the alkylphenol polyoxyethylene ether to the betaine type zwitterionic fluorocarbon surfactant is 1-3: 1-3.
Preferably, the mutual solvent is at least one of ethylene glycol butyl ether, n-propanol and isopropanol.
Preferably, the nonionic surfactant is a nonionic fluorocarbon surfactant. The compound of the nonionic fluorocarbon surfactant and the mutual solvent can form ultra-low interfacial tension, and if the compound is compounded with ethylene glycol monobutyl ether mutual solvent, the interfacial tension is only 0.52 multiplied by 10-3～3.52×10-3mN/m. In addition, the nonionic fluorocarbon surfactant also has strong high temperature resistance and salt resistance (temperature resistance of 110 ℃, and mineralization resistance of 20 multiplied by 10)4mg/L), the HBL value is changed by adjusting the lengths and positions of different groups, so that the molecular structure is determined, the requirements of different oil reservoirs are met, and the water lock effect can be well solved under the conditions of high temperature and high mineralization.
Further preferably, the nonionic surfactant is a polyethylene glycol perfluoro surfactant.
Preferably, the cationic surfactant is at least one of cetyl trimethyl ammonium bromide, alkylphenol ethoxylates and betaine type zwitterionic fluorocarbon surfactant. The cationic surfactant is composed of cetyl trimethyl ammonium bromide, alkylphenol polyoxyethylene ether and betaine type zwitterion fluorocarbon surfactant. In the cationic surfactant, the mass ratio of cetyl trimethyl ammonium bromide to alkylphenol polyoxyethylene to betaine type zwitter-ion fluorocarbon surfactant is 1-3: 1-3.
The application method of the water-locking injury blocking remover adopts the technical scheme that:
the use method of the water-locking injury blocking remover comprises the following steps: and (3) injecting a front acid, a main body treatment fluid and a rear fluid in sequence from a sand washing tool which is put down from an oil pipe or from an oil sleeve annulus, then closing the well for reaction, and opening the well for continuous operation.
The application method of the water lock damage blocking remover is simple and easy to implement, can well solve the water lock effect, and has low cost and obvious oil increasing effect.
In the using process, the dosage of the water-locking damage blocking remover is determined by comprehensive calculation according to the thickness of a reservoir stratum, the porosity and the average pollution radius. Generally, the dosage of the water-lock damage blocking remover is not less than the leakage amount of external fluid during well washing in the operation or oil extraction process. After the injection is finished, the pressure change condition during construction and the pressure recovery condition after the well is closed are determined, and the well closing reaction time is not less than 2 h.
The technical scheme adopted by the water lock injury acidizing fluid is as follows:
a water-lock injury acidizing fluid comprises the following components in percentage by mass: 10-15% of retarding acid, 0.3-1% of corrosion inhibitor, 0.3-0.7% of complexing agent, 0.3-1.7% of clay stabilizer, 0.4-1% of retarding agent, 0.2-0.8% of cleanup additive and the balance of water.
In the water-lock damage acidizing fluid, the low-damage retarded acid is mainly used for pretreating the stratum to remove mechanical impurities and inorganic blockage in a near-wellbore zone, and meanwhile, the pH value of the acid liquid system is always less than 2 under the stratum condition, so that the acid liquid system can be used for removing the mechanical impurities and inorganic blockage in the near-wellbore zoneHydroxide precipitation is effectively avoided; the corrosion inhibitor in the preposed acid solution can effectively prevent the corrosion of the blocking remover to construction equipment and pipelines; the complexing agent can perform complexing reaction with iron ions to prevent the iron ions from generating precipitates; the clay stabilizer can prevent the pollution caused by clay expansion and migration in a reservoir caused by acid liquor; the retarder can be adsorbed on the rock surface to prevent H+The acid rock reaction speed is reduced by contacting with the rock surface; the cleanup additive can reduce the surface tension between the acid liquor and the crude oil, reduce the capillary resistance, adjust the rock wettability and help the acid liquor to flow back; through the synergistic effect of all the components, the complex scale inhibitor has strong complexation performance, thereby having good scale inhibition capability, effectively inhibiting the product precipitation generated by the reaction of the sandstone and the acid liquor, and further avoiding the occurrence of secondary precipitation; meanwhile, the acidizing plugging removal agent has a large acidizing plugging removal range and small corrosivity, and can reduce the corrosion of the construction process to the immobile pipe column.
Preferably, the retarded acid is at least one of a polyhydroic acid and a phosphoric acid.
The polyhydrogen acid is phosphonate compound, which is composed of hydrogen, alkyl, aryl, phosphonate, phosphate, acyl, amine, hydroxyl group, etc. and reacts with fluoride salt to generate hydrofluoric acid. The phosphonate compound contains a plurality of hydrogen ions, the hydrogen ions are decomposed under different stoichiometric conditions through multi-stage ionization, and the concentration of the ionized hydrogen ions is always at a lower level, so that the excessive acid concentration is prevented from greatly eroding rocks in a near-wellbore area.
Preferably, the complexing agent is at least one of diethylenetriamine pentamethylene phosphonic acid and 2-phosphonic butane-1, 2, 4-tricarboxylic acid. The diethylenetriamine pentamethylene phosphonic acid can form various stable complexes with various metal ions, has stable chemical properties and is not easy to decompose in strong acid and alkali media; the 2-phosphonic butane-1, 2, 4-tricarboxylic acid is combined with iron ions to form a complex which is soluble in water, and the chance of precipitation of iron hydroxide is reduced.
Preferably, the corrosion inhibitor is at least one of a mannich base quaternary ammonium salt and a bis-mannich base. The Mannich base quaternary ammonium salt used as the corrosion inhibitor has the characteristics of high temperature resistance, stable structure, good compatibility with other acid liquor additives, low cost and obvious corrosion inhibition effect; the bis-Mannich base has the characteristics of good corrosion inhibition performance, good dissolution and dispersion properties, no precipitation, stable corrosion inhibition performance and the like in acid liquor.
Preferably, the retarder is a copolymer of acrylamide and 2-acrylamido-2-methylpropanesulfonic acid. Compared with other retarders in the prior art, the retarder has good thermal stability (the decomposition temperature exceeds 200 ℃) and good hydrolysis resistance under the condition of high mineralization degree. Meanwhile, the molecular structure contains carboxylic acid group with scale inhibition dispersion performance and sulfonic acid group with strong polarity, so that the calcium tolerance can be improved, and the scale inhibitor has obvious scale inhibition effect on calcium phosphate, calcium carbonate and the like in water.
Preferably, the cleanup additive is at least one of cetyl trimethyl ammonium bromide, alkylphenol ethoxylates and betaine type zwitterionic fluorocarbon surfactant. Further preferably, the cleanup additive consists of cetyl trimethyl ammonium bromide, alkylphenol ethoxylates and betaine type zwitterionic fluorocarbon surfactant. In the cleanup additive, the mass ratio of the cetyl trimethyl ammonium bromide to the alkylphenol polyoxyethylene ether to the betaine type zwitterion fluorocarbon surfactant is 1-3: 1-3. The composite cleanup additive improves the surface/interface activity, greatly reduces the dosage of the surfactant, reduces the medicament cost, and avoids the difficulty in taking account of the effects of reducing the surface tension and increasing the contact angle of a single surfactant.
Preferably, the mutual solvent is at least one of ethylene glycol butyl ether, n-propanol and isopropanol. The mutual solvent is added to reduce the tension of an oil-water interface and the two-phase flow resistance, so that the acid liquor can enter a stratum and can be discharged in time, and the acidification effect can be improved.
Detailed Description
The technical solution of the present invention will be further described with reference to the following embodiments.
The Mannich base quaternary ammonium salt adopted in the specific embodiment is prepared by mixing and heating formaldehyde, N-methylaniline, acetophenone and a small amount of hydrochloric acid for 4 hours to generate Mannich base, then slowly dropwise adding chloroacetic acid, and continuously performing reflux reaction for 4 hours;
the adopted bis-Mannich base is prepared by taking thiourea, benzaldehyde and acetophenone as raw materials and reacting by a two-step method, specifically, Mannich base a is synthesized firstly, and then the Mannich base a, the benzaldehyde and phenylacetaldehyde are reacted for 4 hours at a constant temperature of 110 ℃ according to a molar ratio of 1:1: 1;
the adopted cationic monomer is poly dimethyl diallyl ammonium chloride;
the adopted betaine type amphoteric ion fluorocarbon surfactant is
FSK, the betaine type zwitterion fluorocarbon surfactant can be widely applied to water, acid, alkali and organic polar solvents to effectively reduce the surface tension of the system; the FSK can keep stable performance in aqueous solutions with different concentrations at 0-100 ℃; FSK is effective in moistening when the active ingredient is 0.1%
A fluorocarbon film; even if the solvent acetic acid is neutralized, the performance of FSK is not affected, so the method can be applied to alkaline solution; in addition, unlike other common surfactants, FSK is not affected by high concentration electrolytes such as acids, salts, and the like.
Example 1
The water-lock injury acidizing fluid comprises the following components in percentage by mass: 10% of retarding acid, 0.8% of corrosion inhibitor, 0.3% of complexing agent, 1% of clay stabilizer, 0.5% of retarding agent, 0.7% of cleanup additive and the balance of water; the adopted retarding acid is phosphoric acid, the corrosion inhibitor is Mannich base quaternary ammonium salt, the complexing agent is diethylenetriamine pentamethylene phosphonic acid, the clay stabilizer is a copolymer of acrylamide and a cationic monomer, the retarding agent is a copolymer of acrylamide and 2-acrylamide-2-methylpropanesulfonic acid, and the cleanup additive is composed of hexadecyl trimethyl ammonium bromide, alkylphenol polyoxyethylene ether and FSK; the mass ratio of the hexadecyl trimethyl ammonium bromide to the alkylphenol polyoxyethylene ether to the FSK is 2:1: 1.
The water-lock injury blocking remover comprises a preposed acid, a main body treatment liquid and a postposition liquid; the volume ratio of the preposed acid to the main body treatment liquid to the postposition liquid is 3:5: 3; the preposed acid comprises the following components in percentage by mass: 10% of retarding acid, 0.8% of corrosion inhibitor, 0.3% of complexing agent, 1% of clay stabilizer, 0.5% of retarding agent, 0.7% of cleanup additive and the balance of water; the adopted retarding acid is phosphoric acid, the corrosion inhibitor is Mannich base quaternary ammonium salt, the complexing agent is diethylenetriamine pentamethylene phosphonic acid, the clay stabilizer is a copolymer of acrylamide and a cationic monomer, the retarding agent is a copolymer of acrylamide and 2-acrylamide-2-methylpropanesulfonic acid, and the cleanup additive is composed of hexadecyl trimethyl ammonium bromide, alkylphenol polyoxyethylene ether and FSK; in the cleanup additive, the mass ratio of cetyl trimethyl ammonium bromide, alkylphenol polyoxyethylene ether and FSK is 2:1: 1;
the main body treatment liquid comprises the following components in percentage by mass: 40% of ethanol, 0.5% of nonionic surfactant, 0.8% of mutual solvent and the balance of water; the adopted nonionic surfactant is a polyethylene glycol perfluorinated surfactant, and the mutual solvent is ethylene glycol monobutyl ether;
the postposition liquid comprises the following components in percentage by mass: 1% of ammonium chloride, 0.5% of cationic surfactant and the balance of water; the cationic surfactant is composed of hexadecyl trimethyl ammonium bromide, alkylphenol polyoxyethylene ether and FSK, wherein the mass ratio of the hexadecyl trimethyl ammonium bromide to the alkylphenol polyoxyethylene ether to the FSK is 2:1: 1.
The water lock damage occurs in the drilling and plugging process of Hu 2-48 wells 2016, 7 and 21 days, the yield is reduced from 3.8 t/day to 0.6 t/day, various yield increasing modes are adopted, and the yield is not obviously improved. When the blocking remover damaged by water is used, the prepositive acid, the main body treatment fluid and the postpositive fluid are sequentially extruded into a target layer by adopting a pump truck injection method, a well is closed for 2 hours, construction is continued, the pump pressure is reduced from 29MPa to 16MPa in the continuous construction process, and the oil yield is increased to 4.5 t/day after measures.
Example 2
The water-lock injury acidizing fluid comprises the following components in percentage by mass: 15% of retarding acid, 0.6% of corrosion inhibitor, 0.5% of complexing agent, 1% of clay stabilizer, 0.5% of retarding agent, 0.6% of cleanup additive and the balance of water; the adopted retarding acid is phosphoric acid, the corrosion inhibitor is bis-Mannich base, the complexing agent is diethylenetriamine pentamethylene phosphonic acid, the clay stabilizer is a copolymer of acrylamide and a cationic monomer, the retarding agent is a copolymer of acrylamide and 2-acrylamide-2-methylpropanesulfonic acid, and the cleanup additive is composed of hexadecyl trimethyl ammonium bromide, alkylphenol polyoxyethylene ether and FSK; in the cleanup additive, the mass ratio of cetyl trimethyl ammonium bromide, alkylphenol polyoxyethylene ether and FSK is 1:1: 1.
The water-lock injury blocking remover comprises a preposed acid, a main body treatment liquid and a postposition liquid; the volume ratio of the pre-acid to the main treatment liquid to the post-liquid is 4.5:6: 4.5; the preposed acid comprises the following components in percentage by mass: 15% of retarding acid, 0.6% of corrosion inhibitor, 0.5% of complexing agent, 1% of clay stabilizer, 0.5% of retarding agent, 0.6% of cleanup additive and the balance of water; the adopted retarding acid is phosphoric acid, the corrosion inhibitor is bis-Mannich base, the complexing agent is diethylenetriamine pentamethylene phosphonic acid, the clay stabilizer is a copolymer of acrylamide and a cationic monomer, the retarding agent is a copolymer of acrylamide and 2-acrylamide-2-methylpropanesulfonic acid, and the cleanup additive is composed of hexadecyl trimethyl ammonium bromide, alkylphenol polyoxyethylene ether and FSK; in the cleanup additive, the mass ratio of cetyl trimethyl ammonium bromide, alkylphenol polyoxyethylene ether and FSK is 1:1: 1;
the main body treatment liquid comprises the following components in percentage by mass: 25% of ethanol, 0.8% of nonionic surfactant, 1.5% of mutual solvent and the balance of water; the adopted nonionic surfactant is a polyethylene glycol perfluorinated surfactant; the adopted mutual solvent is n-propanol;
the postposition liquid comprises the following components in percentage by mass: 1% of ammonium chloride, 0.3% of cationic surfactant and the balance of water; the cationic surfactant is composed of hexadecyl trimethyl ammonium bromide, alkylphenol polyoxyethylene ether and FSK, wherein the mass ratio of the hexadecyl trimethyl ammonium bromide to the alkylphenol polyoxyethylene ether to the FSK is 1:1: 1.
The water lock damage occurs in the drilling and plugging process of 2016, 9, 12 days in 92-15 wells in Qing, the yield is reduced from 2.7 t/day to 0.1 t/day, various yield increasing modes are adopted, and the yield is not obviously improved. When the water lock damage blocking remover is used, the prepositive acid, the main body treatment fluid and the postpositive fluid are sequentially extruded into a target layer by adopting a pump truck injection method, the well is closed for 2h, construction is continued, the pump pressure is reduced from 32MPa to 21MPa in the continuous construction process, and the oil yield is increased to 5.1 t/day after measures.
Example 3
The water-lock injury acidizing fluid comprises the following components in percentage by mass: 12% of retarding acid, 0.3% of corrosion inhibitor, 0.3% of complexing agent, 1% of clay stabilizer, 0.5% of retarding agent, 0.2% of cleanup additive and the balance of water; the adopted retarding acid consists of phosphoric acid and polyhydroic acid, the mass ratio of the phosphoric acid to the polyhydroic acid is 10:2, the corrosion inhibitor consists of bis-Mannich base and Mannich base quaternary ammonium salt, the mass ratio of the bis-Mannich base to the Mannich base quaternary ammonium salt is 1:1, the complexing agent is diethylenetriamine pentamethylenephosphonic acid, the clay stabilizer is a copolymer of acrylamide and a cationic monomer, the retarding agent is a copolymer of acrylamide and 2-acrylamide-2-methylpropanesulfonic acid, and the cleanup additive is FSK.
The water-lock injury blocking remover comprises a preposed acid, a main body treatment liquid and a postposition liquid; the volume ratio of the preposed acid to the main body treatment liquid to the postposition liquid is 3:6: 3; the preposed acid comprises the following components in percentage by mass: 12% of retarding acid, 0.3% of corrosion inhibitor, 0.3% of complexing agent, 1% of clay stabilizer, 0.5% of retarding agent, 0.2% of cleanup additive and the balance of water; the adopted retarding acid consists of phosphoric acid and polyhydroic acid, the mass ratio of the phosphoric acid to the polyhydroic acid is 10:2, the corrosion inhibitor consists of bis-Mannich base and Mannich base quaternary ammonium salt, the mass ratio of the bis-Mannich base to the Mannich base quaternary ammonium salt is 1:1, the complexing agent is diethylenetriamine pentamethylenephosphonic acid, the clay stabilizer is a copolymer of acrylamide and a cationic monomer, the retarding agent is a copolymer of acrylamide and 2-acrylamide-2-methylpropanesulfonic acid, and the cleanup additive is hexadecyl trimethyl ammonium bromide.
The main body treatment liquid comprises the following components in percentage by mass: 30% of ethanol, 0.5% of nonionic surfactant, 1% of mutual solvent and the balance of water; the adopted nonionic surface active agent is polyethylene glycol perfluoro surfactant, and the mutual solvent is ethylene glycol monobutyl ether.
The postposition liquid comprises the following components in percentage by mass: 1% of ammonium chloride, 0.4% of cationic surfactant and the balance of water; the cationic surfactant is composed of hexadecyl trimethyl ammonium bromide, alkylphenol polyoxyethylene ether and FSK, wherein the mass ratio of the hexadecyl trimethyl ammonium bromide to the alkylphenol polyoxyethylene ether to the FSK is 1:1: 1.
Water lock damage occurs in the well washing process of 1 month and 15 days of operation in 2017 of Liu 20-10 wells, and the yield is reduced to 0.3 t/day from 2.9 t/day. When the water-lock damage blocking remover is used, the prepositive acid, the main body treatment fluid and the postpositive fluid are sequentially extruded into a target layer by adopting a pump truck injection method, a well is closed for 2h, the pump pressure is reduced from 30MPa to 19MPa in the construction process, and the oil yield is increased to 3.2 t/day after measures.
The water-lock injury blocking remover of embodiments 4 to 11 includes a pre-acid, a main body treatment fluid and a post-fluid; the preposed acid consists of retarding acid, corrosion inhibitor, complexing agent, retarding agent, cleanup additive and water; the main body treatment liquid consists of ethanol, nonionic surfactant, mutual solvent and water; the post liquid consists of ammonium chloride, cationic surfactant and water; the compositions of the pre-acid, the main body treatment fluid and the post-fluid of the water-lock injury blocking remover in each example are shown in Table 1, and the volume ratio of the pre-acid, the main body treatment fluid and the post-fluid is shown in Table 2.
TABLE 1 compositions (% by mass) of the pre-acid, the main treatment liquid and the post-liquid in examples 4 to 11
TABLE 2 volume ratio of pre-acid, bulk treating fluid and post-fluid for examples 4-11
Examples of the experiments
The performance of the water-lock damage blocking remover of examples 1 to 11 was tested.
1) Test for Corrosion Properties
Drying and grinding the simulated rock core, sieving with a 100-mesh sieve, drying the undersize product at 100 deg.C to obtain sample powder, and weighing and recording as G1(ii) a Adding a pre-acid into the sample powder according to the condition that 10ml of the pre-acid is added into each 1g of the sample powder, fully reacting the pre-acid with the sample powder, and placing the sample powder under the constant condition of stratum temperature (100 ℃) for 6 hours; after the reaction, the mixture was filtered through a quantitative filter paper (the weight G of the filter paper was measured)2) Drying to constant weight, weighing the total weight G of the sample powder and the filter paper3The corrosion rate was calculated according to the following formula:
by calculation, the corrosion rates of the examples 1 to 11 are all more than 35%, which is shown in Table 3.
TABLE 3 results of testing the corrosion performance of the pre-acid of examples 1 to 11
2) Corrosion inhibition performance test
The test is carried out according to the performance test method and evaluation index requirements of the corrosion inhibitor for SY/T5405-1996 acidification, the mass concentration of the corrosion inhibitor is 300mg/L at 90 ℃, a static coupon test is carried out for 24 hours, the test results show that the corrosion inhibition rate of the water-locking damage blocking remover of the examples 1-11 is more than 80%, and the specific results are shown in Table 4.
TABLE 4 results of corrosion inhibition performance test of the water-lock damage blocking remover of examples 1 to 11
3) Permeability recovery test for damaged core
The water lock injury blocking remover in example 1 is adopted to carry out tests according to a method for measuring the relative permeability of two-phase fluid in SY/T5345-2007 rock, a method for testing the flow of a SY/T5886 core and evaluation index requirements, the damaged core comes from Liu 20-1 well, Hu 2-7 well and Qing 85-side 12 respectively, the test results are shown in table 5, and the data in table 5 show that the permeability of the damaged core is restored to a certain degree after the blocking remover is applied (see detailed table 5). In addition, the residual acid after displacement is clear and transparent, which shows that the water-locking damage blocking remover in the embodiment 1 can avoid secondary damage and can meet the blocking removal requirement.
Table 5 damaged core displacement test results
Claims (10)
1. The utility model provides a water-lock injury blocking remover, includes leading sour, main part treatment fluid and postposition liquid, its characterized in that: the preposed acid comprises the following components in percentage by mass: 10-15% of retarding acid, 0.3-1% of corrosion inhibitor, 0.3-0.7% of complexing agent, 0.3-1.7% of clay stabilizer, 0.4-1% of retarding agent, 0.2-0.8% of cleanup additive and the balance of water;
the main body treatment liquid comprises the following components in percentage by mass: 20-50% of ethanol, 0.2-1% of nonionic surfactant, 0.5-1.5% of mutual solvent and the balance of water;
the postposition liquid comprises the following components in percentage by mass: 0.2-0.8% of cationic surfactant, 1-1.5% of ammonium chloride and the balance of water.
2. The water-lock injury blocking remover of claim 1, wherein: the volume ratio of the pre-acid to the main body treatment liquid to the post-liquid is 3-6: 3-15: 3-13.
3. The water-lock injury blocking remover of claim 1, wherein: the retarded acid is at least one of polyhydrogen acid and phosphoric acid.
4. The water-lock injury blocking remover of claim 1, wherein: the complexing agent is at least one of diethylenetriamine pentamethylene phosphonic acid and 2-phosphonic acid butane-1, 2, 4-tricarboxylic acid.
5. The water-lock injury blocking remover of claim 1, wherein: the corrosion inhibitor is at least one of a Mannich base quaternary ammonium salt and a bis-Mannich base.
6. The water-lock injury blocking remover of claim 1, wherein: the clay stabilizer is at least one of copolymer of acrylamide and cationic monomer and polydimethyldiallyl ammonium chloride.
7. The water-lock injury blocking remover of claim 1, wherein: the retarder is a copolymer of acrylamide and 2-acrylamido-2-methylpropanesulfonic acid.
8. The water-lock injury blocking remover of claim 1, wherein: the cleanup additive is at least one of cetyl trimethyl ammonium bromide, alkylphenol polyoxyethylene ether and betaine type zwitterion fluorocarbon surfactant.
9. A method of using the water-lock injury blocking remover of claim 1, wherein: the method comprises the following steps: and (3) injecting a front acid, a main body treatment fluid and a rear fluid in sequence from a sand washing tool which is put down from an oil pipe or from an oil sleeve annulus, then closing the well for reaction, and opening the well for continuous operation.
10. A water lock injury acidizing fluid is characterized in that: the composite material comprises the following components in percentage by mass: 10-15% of retarding acid, 0.3-1% of corrosion inhibitor, 0.3-0.7% of complexing agent, 0.3-1.7% of clay stabilizer, 0.4-1% of retarding agent, 0.2-0.8% of cleanup additive and the balance of water.
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