CN108775236A - The increasing injection process of water injection well and its application - Google Patents
The increasing injection process of water injection well and its application Download PDFInfo
- Publication number
- CN108775236A CN108775236A CN201810929411.7A CN201810929411A CN108775236A CN 108775236 A CN108775236 A CN 108775236A CN 201810929411 A CN201810929411 A CN 201810929411A CN 108775236 A CN108775236 A CN 108775236A
- Authority
- CN
- China
- Prior art keywords
- water
- slug
- water injection
- oil pipe
- injection well
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 194
- 239000007924 injection Substances 0.000 title claims abstract description 178
- 238000002347 injection Methods 0.000 title claims abstract description 178
- 238000000034 method Methods 0.000 title claims abstract description 35
- 230000008569 process Effects 0.000 title claims abstract description 28
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 84
- DNIAPMSPPWPWGF-UHFFFAOYSA-N Propylene glycol Chemical compound CC(O)CO DNIAPMSPPWPWGF-UHFFFAOYSA-N 0.000 claims abstract description 51
- 230000003213 activating effect Effects 0.000 claims abstract description 38
- -1 olefin sulfonate Chemical class 0.000 claims abstract description 38
- 239000011734 sodium Substances 0.000 claims abstract description 37
- 229910052708 sodium Inorganic materials 0.000 claims abstract description 37
- JRZJOMJEPLMPRA-UHFFFAOYSA-N olefin Natural products CCCCCCCC=C JRZJOMJEPLMPRA-UHFFFAOYSA-N 0.000 claims abstract description 33
- 239000002253 acid Substances 0.000 claims abstract description 24
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims abstract description 22
- ZMXDDKWLCZADIW-UHFFFAOYSA-N N,N-Dimethylformamide Chemical compound CN(C)C=O ZMXDDKWLCZADIW-UHFFFAOYSA-N 0.000 claims abstract description 21
- 238000011049 filling Methods 0.000 claims abstract description 21
- 239000004721 Polyphenylene oxide Substances 0.000 claims abstract description 17
- 229920000570 polyether Polymers 0.000 claims abstract description 17
- 230000002829 reductive effect Effects 0.000 claims abstract description 15
- RFVNOJDQRGSOEL-UHFFFAOYSA-N 2-hydroxyethyl octadecanoate Chemical compound CCCCCCCCCCCCCCCCCC(=O)OCCO RFVNOJDQRGSOEL-UHFFFAOYSA-N 0.000 claims abstract description 13
- 229950007687 macrogol ester Drugs 0.000 claims abstract description 13
- APSBXTVYXVQYAB-UHFFFAOYSA-M sodium docusate Chemical compound [Na+].CCCCC(CC)COC(=O)CC(S([O-])(=O)=O)C(=O)OCC(CC)CCCC APSBXTVYXVQYAB-UHFFFAOYSA-M 0.000 claims abstract description 13
- CCEKAJIANROZEO-UHFFFAOYSA-N sulfluramid Chemical compound CCNS(=O)(=O)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)F CCEKAJIANROZEO-UHFFFAOYSA-N 0.000 claims abstract description 9
- RLMDOMGMIRVGQY-UHFFFAOYSA-N dichloro-[dichloro(phenyl)silyl]oxy-phenylsilane Chemical compound C=1C=CC=CC=1[Si](Cl)(Cl)O[Si](Cl)(Cl)C1=CC=CC=C1 RLMDOMGMIRVGQY-UHFFFAOYSA-N 0.000 claims abstract description 6
- NLKNQRATVPKPDG-UHFFFAOYSA-M potassium iodide Chemical compound [K+].[I-] NLKNQRATVPKPDG-UHFFFAOYSA-M 0.000 claims description 45
- 230000005764 inhibitory process Effects 0.000 claims description 38
- 239000000203 mixture Substances 0.000 claims description 38
- 238000004140 cleaning Methods 0.000 claims description 35
- QPCDCPDFJACHGM-UHFFFAOYSA-N N,N-bis{2-[bis(carboxymethyl)amino]ethyl}glycine Chemical compound OC(=O)CN(CC(O)=O)CCN(CC(=O)O)CCN(CC(O)=O)CC(O)=O QPCDCPDFJACHGM-UHFFFAOYSA-N 0.000 claims description 32
- 230000000694 effects Effects 0.000 claims description 19
- 239000011248 coating agent Substances 0.000 claims description 18
- 229920001223 polyethylene glycol Polymers 0.000 claims description 17
- UMGDCJDMYOKAJW-UHFFFAOYSA-N thiourea Chemical compound NC(N)=S UMGDCJDMYOKAJW-UHFFFAOYSA-N 0.000 claims description 17
- PIICEJLVQHRZGT-UHFFFAOYSA-N Ethylenediamine Chemical compound NCCN PIICEJLVQHRZGT-UHFFFAOYSA-N 0.000 claims description 16
- QTBSBXVTEAMEQO-UHFFFAOYSA-N acetic acid Substances CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 claims description 16
- 239000001763 2-hydroxyethyl(trimethyl)azanium Substances 0.000 claims description 15
- 235000019743 Choline chloride Nutrition 0.000 claims description 15
- ZLMJMSJWJFRBEC-UHFFFAOYSA-N Potassium Chemical compound [K] ZLMJMSJWJFRBEC-UHFFFAOYSA-N 0.000 claims description 15
- SGMZJAMFUVOLNK-UHFFFAOYSA-M choline chloride Chemical compound [Cl-].C[N+](C)(C)CCO SGMZJAMFUVOLNK-UHFFFAOYSA-M 0.000 claims description 15
- 229960003178 choline chloride Drugs 0.000 claims description 15
- 235000019441 ethanol Nutrition 0.000 claims description 15
- MEFBJEMVZONFCJ-UHFFFAOYSA-N molybdate Chemical compound [O-][Mo]([O-])(=O)=O MEFBJEMVZONFCJ-UHFFFAOYSA-N 0.000 claims description 15
- 229920000747 poly(lactic acid) Polymers 0.000 claims description 15
- 239000004626 polylactic acid Substances 0.000 claims description 15
- 239000011591 potassium Substances 0.000 claims description 15
- 229910052700 potassium Inorganic materials 0.000 claims description 15
- 230000007797 corrosion Effects 0.000 claims description 14
- 238000005260 corrosion Methods 0.000 claims description 14
- YGSDEFSMJLZEOE-UHFFFAOYSA-N salicylic acid Chemical compound OC(=O)C1=CC=CC=C1O YGSDEFSMJLZEOE-UHFFFAOYSA-N 0.000 claims description 14
- 239000012948 isocyanate Substances 0.000 claims description 13
- 150000002513 isocyanates Chemical class 0.000 claims description 13
- 238000013268 sustained release Methods 0.000 claims description 12
- 239000012730 sustained-release form Substances 0.000 claims description 12
- 238000011010 flushing procedure Methods 0.000 claims description 11
- 239000003999 initiator Substances 0.000 claims description 11
- 239000000243 solution Substances 0.000 claims description 11
- NIXOWILDQLNWCW-UHFFFAOYSA-N 2-Propenoic acid Natural products OC(=O)C=C NIXOWILDQLNWCW-UHFFFAOYSA-N 0.000 claims description 10
- 229920002538 Polyethylene Glycol 20000 Polymers 0.000 claims description 10
- KXHPPCXNWTUNSB-UHFFFAOYSA-M benzyl(trimethyl)azanium;chloride Chemical compound [Cl-].C[N+](C)(C)CC1=CC=CC=C1 KXHPPCXNWTUNSB-UHFFFAOYSA-M 0.000 claims description 10
- 239000012744 reinforcing agent Substances 0.000 claims description 10
- 239000003381 stabilizer Substances 0.000 claims description 10
- UWHCKJMYHZGTIT-UHFFFAOYSA-N tetraethylene glycol Chemical compound OCCOCCOCCOCCO UWHCKJMYHZGTIT-UHFFFAOYSA-N 0.000 claims description 10
- SMZOUWXMTYCWNB-UHFFFAOYSA-N 2-(2-methoxy-5-methylphenyl)ethanamine Chemical compound COC1=CC=C(C)C=C1CCN SMZOUWXMTYCWNB-UHFFFAOYSA-N 0.000 claims description 9
- LYCAIKOWRPUZTN-UHFFFAOYSA-N Ethylene glycol Chemical compound OCCO LYCAIKOWRPUZTN-UHFFFAOYSA-N 0.000 claims description 9
- 235000021355 Stearic acid Nutrition 0.000 claims description 9
- QIQXTHQIDYTFRH-UHFFFAOYSA-N octadecanoic acid Chemical group CCCCCCCCCCCCCCCCCC(O)=O QIQXTHQIDYTFRH-UHFFFAOYSA-N 0.000 claims description 9
- OQCDKBAXFALNLD-UHFFFAOYSA-N octadecanoic acid Natural products CCCCCCCC(C)CCCCCCCCC(O)=O OQCDKBAXFALNLD-UHFFFAOYSA-N 0.000 claims description 9
- 239000001509 sodium citrate Substances 0.000 claims description 9
- NLJMYIDDQXHKNR-UHFFFAOYSA-K sodium citrate Chemical compound O.O.[Na+].[Na+].[Na+].[O-]C(=O)CC(O)(CC([O-])=O)C([O-])=O NLJMYIDDQXHKNR-UHFFFAOYSA-K 0.000 claims description 9
- 239000008117 stearic acid Substances 0.000 claims description 9
- HQWKKEIVHQXCPI-UHFFFAOYSA-L disodium;phthalate Chemical compound [Na+].[Na+].[O-]C(=O)C1=CC=CC=C1C([O-])=O HQWKKEIVHQXCPI-UHFFFAOYSA-L 0.000 claims description 8
- FJKROLUGYXJWQN-UHFFFAOYSA-N papa-hydroxy-benzoic acid Natural products OC(=O)C1=CC=C(O)C=C1 FJKROLUGYXJWQN-UHFFFAOYSA-N 0.000 claims description 7
- 229960004889 salicylic acid Drugs 0.000 claims description 7
- AEQDJSLRWYMAQI-UHFFFAOYSA-N 2,3,9,10-tetramethoxy-6,8,13,13a-tetrahydro-5H-isoquinolino[2,1-b]isoquinoline Chemical compound C1CN2CC(C(=C(OC)C=C3)OC)=C3CC2C2=C1C=C(OC)C(OC)=C2 AEQDJSLRWYMAQI-UHFFFAOYSA-N 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 6
- 239000000176 sodium gluconate Substances 0.000 claims description 6
- 229940005574 sodium gluconate Drugs 0.000 claims description 6
- 235000012207 sodium gluconate Nutrition 0.000 claims description 6
- KDYFGRWQOYBRFD-UHFFFAOYSA-N succinic acid Chemical compound OC(=O)CCC(O)=O KDYFGRWQOYBRFD-UHFFFAOYSA-N 0.000 claims description 6
- 125000001797 benzyl group Chemical group [H]C1=C([H])C([H])=C(C([H])=C1[H])C([H])([H])* 0.000 claims description 4
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 claims description 4
- MPNXSZJPSVBLHP-UHFFFAOYSA-N 2-chloro-n-phenylpyridine-3-carboxamide Chemical compound ClC1=NC=CC=C1C(=O)NC1=CC=CC=C1 MPNXSZJPSVBLHP-UHFFFAOYSA-N 0.000 claims description 3
- 239000001384 succinic acid Substances 0.000 claims description 3
- BDUIBJCGBNINBM-UHFFFAOYSA-N acetic acid N'-ethylethane-1,2-diamine Chemical compound CC(O)=O.CC(O)=O.CC(O)=O.CCNCCN BDUIBJCGBNINBM-UHFFFAOYSA-N 0.000 claims 1
- 239000003643 water by type Substances 0.000 abstract 1
- 239000003921 oil Substances 0.000 description 72
- 238000002156 mixing Methods 0.000 description 20
- 239000011435 rock Substances 0.000 description 16
- 239000010779 crude oil Substances 0.000 description 9
- 239000003814 drug Substances 0.000 description 9
- 238000002360 preparation method Methods 0.000 description 9
- 238000000576 coating method Methods 0.000 description 8
- 239000007788 liquid Substances 0.000 description 8
- 239000002245 particle Substances 0.000 description 8
- 238000004073 vulcanization Methods 0.000 description 8
- 238000005406 washing Methods 0.000 description 8
- 239000004927 clay Substances 0.000 description 7
- 239000008235 industrial water Substances 0.000 description 6
- 208000027418 Wounds and injury Diseases 0.000 description 5
- 230000006378 damage Effects 0.000 description 5
- 208000014674 injury Diseases 0.000 description 5
- 240000000203 Salix gracilistyla Species 0.000 description 4
- 125000001931 aliphatic group Chemical group 0.000 description 4
- 230000003190 augmentative effect Effects 0.000 description 4
- 230000000903 blocking effect Effects 0.000 description 4
- 230000000052 comparative effect Effects 0.000 description 4
- 238000001816 cooling Methods 0.000 description 4
- 238000005520 cutting process Methods 0.000 description 4
- 230000006837 decompression Effects 0.000 description 4
- 238000011161 development Methods 0.000 description 4
- 238000004945 emulsification Methods 0.000 description 4
- 238000005469 granulation Methods 0.000 description 4
- 230000003179 granulation Effects 0.000 description 4
- 238000010438 heat treatment Methods 0.000 description 4
- 230000001976 improved effect Effects 0.000 description 4
- 239000004615 ingredient Substances 0.000 description 4
- 238000004519 manufacturing process Methods 0.000 description 4
- 238000002844 melting Methods 0.000 description 4
- 230000008018 melting Effects 0.000 description 4
- 230000009467 reduction Effects 0.000 description 4
- 238000007789 sealing Methods 0.000 description 4
- 238000005507 spraying Methods 0.000 description 4
- 238000010792 warming Methods 0.000 description 4
- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonium chloride Substances [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 description 3
- 206010016825 Flushing Diseases 0.000 description 3
- 239000002202 Polyethylene glycol Substances 0.000 description 3
- 239000004568 cement Substances 0.000 description 3
- 230000008859 change Effects 0.000 description 3
- 238000010276 construction Methods 0.000 description 3
- 230000007774 longterm Effects 0.000 description 3
- 239000000463 material Substances 0.000 description 3
- 230000005012 migration Effects 0.000 description 3
- 238000013508 migration Methods 0.000 description 3
- 239000002352 surface water Substances 0.000 description 3
- KAKZBPTYRLMSJV-UHFFFAOYSA-N Butadiene Chemical group C=CC=C KAKZBPTYRLMSJV-UHFFFAOYSA-N 0.000 description 2
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical group [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 2
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 2
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 2
- 230000009471 action Effects 0.000 description 2
- 235000019270 ammonium chloride Nutrition 0.000 description 2
- 230000015556 catabolic process Effects 0.000 description 2
- 239000013043 chemical agent Substances 0.000 description 2
- 239000002734 clay mineral Substances 0.000 description 2
- 238000006731 degradation reaction Methods 0.000 description 2
- 238000006073 displacement reaction Methods 0.000 description 2
- 239000000839 emulsion Substances 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 230000007613 environmental effect Effects 0.000 description 2
- 150000002148 esters Chemical class 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 230000013011 mating Effects 0.000 description 2
- 230000007246 mechanism Effects 0.000 description 2
- 229910021645 metal ion Inorganic materials 0.000 description 2
- 239000005416 organic matter Substances 0.000 description 2
- 230000036961 partial effect Effects 0.000 description 2
- DFLCZDIXTAAMLZ-UHFFFAOYSA-N phthalic acid;sodium Chemical compound [Na].OC(=O)C1=CC=CC=C1C(O)=O DFLCZDIXTAAMLZ-UHFFFAOYSA-N 0.000 description 2
- QQONPFPTGQHPMA-UHFFFAOYSA-N propylene Natural products CC=C QQONPFPTGQHPMA-UHFFFAOYSA-N 0.000 description 2
- 125000004805 propylene group Chemical group [H]C([H])([H])C([H])([*:1])C([H])([H])[*:2] 0.000 description 2
- 239000004576 sand Substances 0.000 description 2
- SPEUIVXLLWOEMJ-UHFFFAOYSA-N 1,1-dimethoxyethane Chemical group COC(C)OC SPEUIVXLLWOEMJ-UHFFFAOYSA-N 0.000 description 1
- QGZKDVFQNNGYKY-UHFFFAOYSA-O Ammonium Chemical compound [NH4+] QGZKDVFQNNGYKY-UHFFFAOYSA-O 0.000 description 1
- HFIABUUUVQIIKC-UHFFFAOYSA-N C(CCCCC(C)C)SCCCCCC(C)C.C(CCC(=O)O)(=O)O Chemical compound C(CCCCC(C)C)SCCCCCC(C)C.C(CCC(=O)O)(=O)O HFIABUUUVQIIKC-UHFFFAOYSA-N 0.000 description 1
- VIQJCEGYVDRIKL-UHFFFAOYSA-N C(CCCCCCC)S(=O)(=O)N.[F] Chemical compound C(CCCCCCC)S(=O)(=O)N.[F] VIQJCEGYVDRIKL-UHFFFAOYSA-N 0.000 description 1
- NRSBLPPFZPAPCV-UHFFFAOYSA-N CCl(C)(C)CC1=CC=CC=C1 Chemical compound CCl(C)(C)CC1=CC=CC=C1 NRSBLPPFZPAPCV-UHFFFAOYSA-N 0.000 description 1
- 235000005979 Citrus limon Nutrition 0.000 description 1
- 244000131522 Citrus pyriformis Species 0.000 description 1
- WTBIAPVQQBCLFP-UHFFFAOYSA-N N.N.N.CC(O)=O.CC(O)=O.CC(O)=O.CC(O)=O.CC(O)=O Chemical compound N.N.N.CC(O)=O.CC(O)=O.CC(O)=O.CC(O)=O.CC(O)=O WTBIAPVQQBCLFP-UHFFFAOYSA-N 0.000 description 1
- QAOWNCQODCNURD-UHFFFAOYSA-L Sulfate Chemical compound [O-]S([O-])(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-L 0.000 description 1
- 239000004480 active ingredient Substances 0.000 description 1
- 150000001336 alkenes Chemical class 0.000 description 1
- 230000008901 benefit Effects 0.000 description 1
- 239000003153 chemical reaction reagent Substances 0.000 description 1
- 238000004891 communication Methods 0.000 description 1
- 230000007423 decrease Effects 0.000 description 1
- 230000001934 delay Effects 0.000 description 1
- GUJOJGAPFQRJSV-UHFFFAOYSA-N dialuminum;dioxosilane;oxygen(2-);hydrate Chemical compound O.[O-2].[O-2].[O-2].[Al+3].[Al+3].O=[Si]=O.O=[Si]=O.O=[Si]=O.O=[Si]=O GUJOJGAPFQRJSV-UHFFFAOYSA-N 0.000 description 1
- KPUWHANPEXNPJT-UHFFFAOYSA-N disiloxane Chemical compound [SiH3]O[SiH3] KPUWHANPEXNPJT-UHFFFAOYSA-N 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 239000004744 fabric Substances 0.000 description 1
- 230000002349 favourable effect Effects 0.000 description 1
- 230000006870 function Effects 0.000 description 1
- PCHJSUWPFVWCPO-UHFFFAOYSA-N gold Chemical compound [Au] PCHJSUWPFVWCPO-UHFFFAOYSA-N 0.000 description 1
- 239000010931 gold Substances 0.000 description 1
- 229910052737 gold Inorganic materials 0.000 description 1
- 125000000623 heterocyclic group Chemical group 0.000 description 1
- 229910052900 illite Inorganic materials 0.000 description 1
- 239000012535 impurity Substances 0.000 description 1
- 230000002401 inhibitory effect Effects 0.000 description 1
- 150000002500 ions Chemical class 0.000 description 1
- 229910052742 iron Inorganic materials 0.000 description 1
- IQPQWNKOIGAROB-UHFFFAOYSA-N isocyanate group Chemical group [N-]=C=O IQPQWNKOIGAROB-UHFFFAOYSA-N 0.000 description 1
- 230000000670 limiting effect Effects 0.000 description 1
- 230000005923 long-lasting effect Effects 0.000 description 1
- 229910052901 montmorillonite Inorganic materials 0.000 description 1
- VGIBGUSAECPPNB-UHFFFAOYSA-L nonaaluminum;magnesium;tripotassium;1,3-dioxido-2,4,5-trioxa-1,3-disilabicyclo[1.1.1]pentane;iron(2+);oxygen(2-);fluoride;hydroxide Chemical compound [OH-].[O-2].[O-2].[O-2].[O-2].[O-2].[F-].[Mg+2].[Al+3].[Al+3].[Al+3].[Al+3].[Al+3].[Al+3].[Al+3].[Al+3].[Al+3].[K+].[K+].[K+].[Fe+2].O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2 VGIBGUSAECPPNB-UHFFFAOYSA-L 0.000 description 1
- 238000012856 packing Methods 0.000 description 1
- 239000002861 polymer material Substances 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 230000002441 reversible effect Effects 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 238000001179 sorption measurement Methods 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 229940124530 sulfonamide Drugs 0.000 description 1
- 150000003456 sulfonamides Chemical class 0.000 description 1
- 230000001360 synchronised effect Effects 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
- 238000005829 trimerization reaction Methods 0.000 description 1
- 229920003169 water-soluble polymer Polymers 0.000 description 1
Classifications
-
- 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
- E21B43/20—Displacing by water
-
- 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
- C09K8/524—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/584—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific 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
-
- 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
- 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)
- Chemical & Material Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Physics & Mathematics (AREA)
- Fluid Mechanics (AREA)
- Geochemistry & Mineralogy (AREA)
- Environmental & Geological Engineering (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Detergent Compositions (AREA)
Abstract
The invention discloses a kind of increasing injection process of water injection well and its applications comprising following steps：Organic de-plugging slug is just being squeezed into from oil pipe；Again by activating agent slug after oil pipe just squeezes into, then replacement clear water is just being squeezed by oil pipe, machine de-plugging slug and activating agent slug are pushed into distal end；Water injection well is closed so valve, the 10%~20% of water injection pressure before keeping water filling well pressure to be reduced to measure naturally.Wherein, organic de-plugging slug is mainly made of three macrogol ester of C8-10- aliphatic acid, propylene glycol block polyether, 1,1,3,3- tetra- chloro- 1,3- diphenyl disiloxane and dimethylformamide；Activating agent slug is mainly made of Aerosol OT, α-sodium olefin sulfonate, N- ethylperfluoro octyl sulfonamide second alcohol and waters.This method can effectively reduce water injection well and start pressure, alleviate water injection well later stage scaling degree, realize stake initial stage water injection well fixed tubular column increasing injection.
Description
Technical field
The present invention relates to reservoir exploitation technical fields, increasing injection process in particular to water injection well and its
Using.
Background technology
With going deep into for exploration and development, " three-lows " feature is increasingly presented in exploitation oil reservoir, and development difficulty increases, low-permeability oilfield
Also the exploitation of tight sandstone reservoir is slowly turned to.Tight sandstone reservoir is influenced by stratum energy, is generally developed using Advance Water Injection,
It improves block and develops overall yield.After tight sandstone reservoir puts into waterflooding extraction, water injection pressure is high and the rate of climb is fast, is not achieved
Injection allocation well increases year by year, and by taking the long areas celebrating Long-dong oilfield Bai Mazhong as an example, stake initial stage be averaged water injection pressure 14.0MPa, at present pressure
Power 18.5MPa, rate of pressure rise are 0.53MPa/, and it is notable that part well high pressure shorts problematic phenomenon.Tight sandstone reservoir is noted
Contradiction is adopted, stratum energy has been seriously affected, reduces whole block development efficiency.Therefore, existing water injection well is there are nearly pit shaft
Band fouling and clogging degree is serious, and the water injection pressure rate of climb, comparatively fast, augmented injection period are short, and workover treatment frequency is higher, and then causes
It is higher that oil field integrates production cost.
Invention content
First of the present invention is designed to provide a kind of increasing injection process of water injection well, can effectively release
Pit shaft land section blocks, and reduces water injection well and starts pressure.
Second object of the present invention is to provide the increasing injection process of above-mentioned water injection well in tight sandstone reservoir
The application that stake initial stage high pressure is shorted, to realize stake initial stage water injection pipe fixed tubular column increasing injection.
The present invention solves its technical problem using following technical scheme to realize.
The present invention provides a kind of increasing injection processes of water injection well comprising following steps：
Organic de-plugging slug is just being squeezed into from oil pipe；
Again by activating agent slug after oil pipe just squeezes into, then replacement clear water is just being squeezed by oil pipe, by machine de-plugging
Slug and activating agent slug push to distal end；
All valves of water injection well are closed, so that water filling well pressure is reduced to water filling before just squeezing into organic de-plugging slug naturally
The 10%~20% of pressure；
Wherein, organic de-plugging slug is mainly by three macrogol ester of C8-10- aliphatic acid, propylene glycol block polyether, 1, and 1,3,
Tetra- chloro- 1,3- diphenyl disiloxane of 3- and dimethylformamide composition；
Activating agent slug is mainly by Aerosol OT, α-sodium olefin sulfonate, N- ethylperfluoro octyl sulphonyl
Amine second alcohol and water forms.
The present invention also provides a kind of increasing injection processes of above-mentioned water injection well to bet initial stage in tight sandstone reservoir
Application.
The present invention first passes through organic de-plugging slug, releases organic matter, emulsification of crude oil blocking, cleans rock surface oil film, then
By injecting activating agent slug to inhibiting the expansion of reservoir deep clay, water injection meter interfacial tension is reduced, Existence of Global Solution is except reservoir
Water-sensitive, liquid lock injury, change rock wettability, reduce rock surface water film thickness, expand water stream channel radius, reduce water injection well
Start pressure.Valve is closed after being pushed again by replacement clear water and carries out nature reduced pressure operation, enabling is fully solved
Stifled decompression, to be combined by construction technology and the product of injection, one-stop operation reaches is imitated for a long time, releases nearly pit shaft area
Partial Blocking reduces water injection well and starts pressure, alleviate water injection well later stage scaling degree, delay the water injection pressure rate of climb, extends
The augmented injection period reduces workover treatment frequency, saves oil field and integrates production cost, realizes the decompression of stake initial stage water injection well fixed tubular column
Augmented injection.
Specific implementation mode
It, below will be to embodiment party of the present invention to keep the purpose, technical scheme and advantage of embodiment of the present invention clearer
Technical solution in formula is clearly and completely described.The person that is not specified actual conditions in embodiment or embodiment, according to routine
The condition that condition or manufacturer suggest carries out.Reagents or instruments used without specified manufacturer, being can be by commercially available purchase
Buy the conventional products of acquisition.
The increasing injection process for being related to water injection well of embodiment of the present invention and its application are carried out specifically below
It is bright.
A kind of increasing injection process for water injection well that embodiment of the present invention provides comprising following steps：
S1, organic de-plugging slug is just being squeezed into from oil pipe.
Specifically, it in order to enable organic de-plugging slug can be acted in water injection well well, needs first to wash water
Well is dredged, to improve the functioning efficiency of organic de-plugging slug and subsequent medicament.Therefore, in some embodiments,
It, can be by water injection well channel by clear water reacting cycle well-flushing by clear water reacting cycle well-flushing before injecting organic de-plugging slug
In cause the partial impurities back flush blocked to come out, in some embodiments, the discharge capacity of the clear water of reacting cycle well-flushing is 500L/
Min-700L/min, the clear water of the discharge capacity enable to clear water can quickly the flowing in well it is well, and miscellaneous to the part of closure
Matter is impacted well, and then reaches good reverse circulation washing effect, without because discharge capacity is too small so that flushing effect
Difference will not to rehearse and excessive cause flow condition bad.Further, in some embodiments, reacting cycle well-flushing it is clear
Total dosage of water can be 0.8~2 hole volume.
Specifically, organic de-plugging slug is mainly by three macrogol ester of C8-10- aliphatic acid, propylene glycol block polyether, 1,1,
Tetra- chloro- 1,3- diphenyl disiloxane of 3,3- and dimethylformamide composition.Wherein, three macrogol ester of C8-C10 aliphatic acid can
Reducing crude oil viscosity degree is reduced, part Long carbon chain organic plugging object is dissolved.Propylene glycol block polyether has duct internal emulsification crude oil good
Good demulsification ability, while can prevent later stage injection water from emulsion again occurs with crude oil.Tetra- chloro- 1,3- hexichol of 1,1,3,3-
Base disiloxane can highly clean rock surface oil stain, assemble dispersed crude oil drop in rock duct, reduce liquid lock injury；Two
Methyl formyl as alembroth, can washing oil, and can preferably dissolve and dispersed organic matter blocks, make organic de-plugging slug with
Water dissolves each other, and reduces the emulsification injury of working fluid fluid.Therefore, organic de-plugging slug containing above-mentioned four kinds of material compositions can be total to
Same-action expands water stream channel radius in the blocking portion in well.
In order to enable organic de-plugging slug has more preferably plugging removal effect, need by the ingredient in organic de-plugging slug according to
The ratio of science is configured, and can be cooperated between various compositions, therefore, some embodiments, organic solution
In stifled slug, the weight percent of three macrogol ester of C8-10- aliphatic acid is 10~15%, the weight of propylene glycol block polyether
Percentage is that the weight percent of 10~15%, 1,1,3,3- tetra- chloro- 1,3- diphenyl disiloxane is 5~10%, and surplus is
The dimethyl formyl.
When carrying out dissolving dredging by organic de-plugging slug, the stopping state in pit shaft is than more serious, liquid communication
Ability is poor, therefore, in some embodiments, is injected using small displacement when injecting organic de-plugging slug.Specifically, by organic solution
The discharge capacity that stifled slug is just being squeezed into from oil pipe is 30L/min-50L/min, and organic de-plugging slug of the displacement size can be first
Phase has good mobility in well, acts on well runner.Wherein, organic in order to sufficiently achieve plugging removal effect
Total dosage of de-plugging slug is 1.5~2 oil pipe internal volumes.The equipment for carrying out organic de-plugging slug injection can be selected with single
To the high-pressure plunger pump of valve, junction is hard sealing.
S2, activating agent slug is just being squeezed into from oil pipe, then is just squeezing into replacement clear water by oil pipe, by machine de-plugging section
Plug and activating agent slug push to distal end.
Specifically, activating agent slug is mainly pungent by Aerosol OT, α-sodium olefin sulfonate, N- ethylperfluoros
Base sulfonamide second alcohol and water forms.Aerosol OT and α-sodium olefin sulfonate in activating agent slug pass through collaboration
Effect reduces the interfacial tension of dissolving, reduces clay deep migration degree, and Existence of Global Solution removes the water fire extinguishing of reservoir；N- ethyls are complete
Fluorine octyl sulfonamide ethyl alcohol can reduce the surface tension of solution, change rock wettability, reduce rock surface water film thickness, expand
Water stream channel radius.
In some embodiments, the weight percent of Aerosol OT is 5~8%, α-sodium olefin sulfonates
Weight percent be the weight percent of 8~10%, N- ethylperfluoro octyl sulfonamide ethyl alcohol be 2~3%, surplus is
Water.The effect between various components can be fully combined by the proportioning between the above-mentioned various compositions of activating agent slug so that each
Kind component can cooperate well.
Preliminary dredging has been carried out to flow channel for liquids after organic de-plugging slug injects water injection well, and then improves channel
Mobility, and then in some embodiments, injected using high discharge capacity when injecting activating agent slug, specifically, by activating agent
The discharge capacity that slug is just being squeezed into from oil pipe is 500L/min-700L/min.It can be made by the activating agent slug injection of huge discharge
Activating agent slug can quickly flow in the channel in well, adapt to the runner after organic de-plugging slug effect.Further,
It is preferred that total dosage of activating agent slug is 15~20 oil pipe internal volumes, so that its dosage can fully meet decompression de-plugging
It needs.Wherein, injection device can be 700 type cementing trucks.
Further, since the stopping state in water injection well being mainly distal end compares concentration, as far as possible will
Liquid acts on distal end, therefore, replacement clear water is just being squeezed by oil pipe, machine de-plugging slug and activating agent slug are pushed to
Distally, the utilization ratio of organic de-plugging slug and activating agent slug is improved.Specifically, the discharge capacity of injection replacement clear water can be
500L/min-700L/min, the total dosage for replacing clear water are 20~25 oil pipe internal volumes.The dosage and discharge capacity of the replacement clear water
Push effect well can be played.Its injection device may be 700 type cementing trucks.
S3, water injection well valve is closed, so that water filling well pressure is reduced to naturally before just squeezing into organic de-plugging slug
The 10%~20% of water injection pressure.
By closing water injection well valve, liquid is enabled to fully can to go out to carry out to the blocking in nearly pit shaft area in well
Effect carries out natural diffuseness pressure in water filling well pressure and continuously decreases.
Further, in order to enable water injection well can keep good water injection pressure for a long time, alleviate the fouling of water injection well later stage
Degree, in some embodiments, the increasing injection process of the water injection well further includes following S4 steps.
S4, after water filling well pressure is reduced to 10%~20% of water injection pressure before measure naturally, open water injection well at the top of
Oil pipe cock and tubing valve inject water-soluble slow-releasing type inhibition cleaning antiscale by oil pipe.
Water-soluble slow-releasing type inhibition cleaning antiscale can in injecting water can slow mechanism dissolved, pass through the clear antiscale of sustained release inhibition
Agent ingredient can release different type fouling and clogging object and inhibit secondly secondary generation, have to clay and contract by force swollen, can reduce hollow billet resistance
The performance of power, is conducive to it and acts on water injection well long-lasting nature, gradually improves water injection well high pressure and shorts present situation.
It should be noted that the center valve of water injection well is in normally open in above-mentioned S3 and S4 steps.
Further, in some embodiments, water-soluble slow-releasing type inhibition cleaning antiscale is mainly by following parts by weight
Group is grouped as：20~37 parts of de-plugging agent, 10~15 parts of stabilizer, 10~15 parts of injection agent, 3~5 parts of coating agent, corrosion inhibiter 3~5
Part, 25~35 parts of sustained release agent, 1~2 part of reinforcing agent and 0.5~1 part of initiator.
In some embodiments, de-plugging agent is mainly by N- beta-hydroxies ethyl-3-acetic acid ethylenediamine, diethylene triamine pentacetic acid (DTPA)
It is formed with salicylic acid；N- beta-hydroxies ethyl-3-acetic acid ethylenediamine, diethylene triamine pentacetic acid (DTPA) and salicylic weight ratio be 10~
20：7~12：3~5.Stabilizer is mainly made of benzyltrimethylammonium chloride and choline chloride, it is preferable that benzyl trimethyl chlorine
The weight ratio for changing ammonium and choline chloride is 5~8：5~7.Injection agent is mainly by α-sodium olefin sulfonate and neopelex
Composition, it is preferable that the weight ratio of α-sodium olefin sulfonate and neopelex in injection agent is 3~5：7~10.Coating
Agent is stearic acid.Corrosion inhibiter is mainly by N, N'- di-o-tolyls thiocarbamide, potassium iodide and potassium molybdate composition, wherein N, N'- bis- are adjacent
The weight ratio of tolylthiourea, potassium iodide and potassium molybdate is 1~2：1~1.5：1~1.5.Sustained release agent mainly by polylactic acid and gathers
Ethylene glycol 20000 forms, wherein polylactic acid and the weight ratio of PEG 20000 are 22~30：3~5.Reinforcing agent mainly by
One or more and acrylic acid composition in sodium citrate, sodium gluconate, sodium phthalate, wherein acrylic acid and lemon
One or more weight ratios in sour sodium, sodium gluconate, sodium phthalate are 8~15：2~5.Initiator is mainly by three
Contracting tetraethylene glycol and isocyanates composition, wherein the weight ratio of tetraethylene-glycol and isocyanates is 3~7：2~3.
Specifically, wherein sustained release agent such as polylactic acid and PEG 20000 are all high molecular weight water soluble polymer materials
Material has itself slow degradation characteristic, and reservoir is not injured after degradation, and enhanced dose modified under initiator effect, water solubility rate
It will slow down, this will delay inhibition cleaning antiscale active ingredient deenergized period significantly.
De-plugging agent such as N- beta-hydroxies ethyl-3-acetic acid ethylenediamine, diethylene triamine pentacetic acid (DTPA) and salicylic acid have weak acid
Property, solution ph can be reduced, rock surface Zate current potentials are improved, the synchronous water that increases is in rock surface contact angle, to carbonate scale
With certain solvability.N- beta-hydroxies ethyl-3-acetic acid ethylenediamine, diethylene triamine pentacetic acid (DTPA) are to divalent gold in tamper
Category ion progress heterocycle, which chelates to be formed, dissolves in water chelating molecule, further releases and blocks carbonate scale and sulfate scale, salicylic acid
It is pi-conjugated that P- can be formed with bivalent metal ion, slowly remove tamper；N- beta-hydroxies ethyl-3-acetic acid ethylenediamine, divinyl three
Triamine pentaacetic acid chelates water flooding bivalent metal ion while removing tamper, by above-mentioned mechanism, inhibits tamper
Secondary fouling.
Corrosion inhibiter such as N, N'- di-o-tolyls thiocarbamide, potassium iodide and potassium molybdate are that other in solid, with this patent are changed
Learning substance has favorable compatibility and compatibility, conducive to cleaning antiscale is slowed down to tube corrosion, reduces the corrosion rate of injection water,
Iron dirt is reduced to generate.It is a long-term process, water-soluble slow-releasing type inhibition cleaning antiscale since small bits of clay is expanded and migrated
Slow release benzyltrimethylammonium chloride and choline chloride ingredient, to illite in clay mineral and montmorillonite ingredient by from
The strong adsorptivity and lattice of sub- effect fill, and reduce small bits of clay migration and expansion, so that clay mineral is contracted by force swollen, increase reservoir water
The aperture of circulation road.
Injection agent such as α-sodium olefin sulfonate and neopelex have the reduction solution interface of high performance-price ratio
Power performance reduces injection water in rock duct internal hair pipe resistance.
Therefore, by said components and proportioning be chosen so that water-soluble slow-releasing type inhibition cleaning antiscale pass through it is long-term
Slow release makes injection water have snaking, antiscale, corrosion inhibition, anti-clayswelling and low interfacial tension characteristic in injecting in water, from
And high pressure shorts the increasing injection of well, efficiently delays and inhibits stake initial stage well unlifting pressure trend.
Further, above-mentioned water-soluble slow-releasing type inhibition cleaning antiscale is prepared by the following method：
Whole N- beta-hydroxies ethyl-3-acetic acid ethylenediamine, diethylene triamine pentacetic acid (DTPA), bigcatkin willow are added first in mixing machine
Acid, benzyltrimethylammonium chloride, choline chloride, α-sodium olefin sulfonate, neopelex, N, N'- di-o-tolyl sulphur
Urea, potassium iodide and potassium molybdate mix 20~30min in mixing machine；Then it is added in the spraying system of vulcanization bed seed-coating machine
Whole stearic acid, slow heating are warming up to 70~72 DEG C；Mixture in first time mixing machine is slowly added to vulcanization bed coating
Machine forms 2~3mm single-sizes；After particle cooling, by particle and the whole polylactic acid of addition, polyethylene glycol in mixing machine
20000, one or more and 10~15min of mixing in acrylic acid and sodium citrate, sodium gluconate, sodium phthalate,
Double screw extruder temperature is increased to 160~165 DEG C, and mixture in its second of mixing machine, which is added to double screw extruder, to be thrown
Material mouth, and whole tetraethylene-glycols and isocyanates are dropped evenly, extruder vacuum switch is opened, through double screw extruder
Melting squeezes out, cutting granulation, forms the water-soluble slow-releasing type inhibition cleaning antiscale product of 3~4mm.
In order to enable water-soluble slow-releasing type inhibition cleaning antiscale can carry out mobilization and be divided fully in water injection well
Cloth, and also to the mobility of water-soluble slow-releasing type inhibition cleaning antiscale is kept, in some embodiments, water-soluble slow-releasing type
Inhibition cleaning antiscale is added in batches by slowly low dose of.Specifically, added by conical hopper from oil pipe at the top of water injection well
Enter, each addition is 5~10kg, and addition speed is 0.5~1kg/min, and weight is 150~300kg in addition.
Due to tight sandstone reservoir since pore throat is tiny, clay content is high, and water-sensitive, liquid lock injury are serious, are thrown in water injection well
Pressure is high after note, and water injection well stake initial stage pressure ascensional range is big, influences block whole development.
Therefore, some embodiments of the present invention additionally provide the increasing injection process of above-mentioned water injection well in fine and close sand
Rock reservoir bets the application during initial stage high pressure is shorted.
Chemical agent in embodiment of the present invention is corrosion-free to flow string, and dosing method is special without packing, pressurization etc.
It is required that operation pressure is within the scope of flow string pressure limiting, without removing and replacing flow string, it can be achieved that fixed tubular column is depressured
Augmented injection reduces construction labor intensity, saves operating cost.High and low discharge capacity injection makes corresponding chemical agent be sent out in reservoir
Best-of-breed functionality is waved, while matching the action characteristic of medicament；It crosses replacement and medicament can be improved in entrance reservoir deep；Pass through closing well nature
Decompression, can be improved de-plugging and the rock surface adsorption effect of medicament, also be conducive to the addition of medicament, reduce job safety trend of environmental protection
Danger.Organic de-plugging slug can reduce reducing crude oil viscosity degree, dissolve part Long carbon chain organic plugging object, have to duct internal emulsification crude oil
Good demulsification ability, while can prevent later stage injection water from emulsion again occurs with crude oil, it can highly clean rock surface
Oil stain assembles dispersed crude oil drop in rock duct, reduces liquid lock injury.Activating agent slug can effectively reduce molten bound on solutions
Face tension reduces clay deep migration degree, and Existence of Global Solution removes the water fire extinguishing of reservoir, while can change rock wettability,
Rock surface water film thickness is reduced, water stream channel radius is expanded.The slow release of water-soluble slow-releasing type inhibition cleaning antiscale extends
The action period of medicament reduces workover treatment frequency, directly to be added from oil pipe, reduces operating cost, tight sand is made to store up
Layer stake initial stage well achievees the purpose that increasing injection.
The feature and performance of the present invention are described in further detail with reference to embodiments.
Embodiment 1
A kind of increasing injection process of water injection well provided in this embodiment, its step are as follows：
A, injection well tubing and sleeve valve are opened, with well-washing truck (clear water) reacting cycle with 500L/min/min well-flushings 1
After hole volume, sleeve valve is closed.
B, organic de-plugging section of 1.5 oil pipe internal volumes is just being squeezed into from oil pipe with 30L/min discharge capacities.
C, the activating agent slug for just squeezing into 15 oil pipe internal volumes from oil pipe with 500L/min discharge capacities, is arranged with 500L/min
Amount replaces the clear water of 20 oil pipe internal volumes.
D, all valves of water injection well are closed, water filling well pressure is kept to be reduced to water injection pressure 10% before measure naturally.
E, oil pipe cock and tubing valve at the top of water injection well are opened, slowly low dose is directly added into water into oil pipe in batches
Dissolubility slow-release inhibition cleaning antiscale.
G, oil pipe cock at the top of water injection well is closed, normal water filling is restored.
Wherein, organic de-plugging slug is by three macrogol ester of C8-10 aliphatic acid, propylene glycol block polyether, 1,1,3,3- tetra-
Chloro- 1,3- diphenyl disiloxane and dimethylformamide composition.In terms of the weight percent in organic de-plugging slug, C8-
Three macrogol ester weight percent of 10- aliphatic acid is 10%, and propylene glycol block polyether weight percent is 10%, 1,1,3,3-
Four chloro- 1,3- diphenyl disiloxane weight percent are 5%, and surplus is dimethyl formyl.
Wherein, activating agent slug is Aerosol OT, a- sodium olefin sulfonates, N- ethylperfluoro octyl sulphonyl
Amine second alcohol and water forms.In terms of the weight percent in activating agent slug, Aerosol OT weight percent
For 5%, α-sodium olefin sulfonate weight percent be 8%, N- ethylperfluoro octyl sulfonamide ethyl alcohol weight percent it is 2%,
Surplus is industrial water.
It is directly from water filling that slowly low dose is directly added into water-soluble slow-releasing type inhibition cleaning antiscale into oil pipe in batches
It is added by conical hopper in oil pipe at the top of well, each addition is 5kg, and addition speed is 0.5kg/min, and weight is added and is
150kg。
Water-soluble slow-releasing type inhibition cleaning antiscale is grouped as by the group of following parts by weight：20 parts of de-plugging agent, stabilizer 10
Part, 10 parts of injection agent, 3 parts of coating agent, 3 parts of corrosion inhibiter, 25 parts of sustained release agent, 1 part of reinforcing agent and 0.5 part of initiator.
Wherein, de-plugging agent is made of N- beta-hydroxies ethyl-3-acetic acid ethylenediamine, diethylene triamine pentacetic acid (DTPA) and salicylic acid；N-
Beta-hydroxy ethyl-3-acetic acid ethylenediamine, diethylene triamine pentacetic acid (DTPA) and salicylic weight ratio are 10：7：3.Stabilizer is by benzyl
The weight ratio of trimethyl ammonium chloride and choline chloride composition, benzyltrimethylammonium chloride and choline chloride is 5：5.Injection agent is by α-
Sodium olefin sulfonate and neopelex form, the weight of α-sodium olefin sulfonate and neopelex in injection agent
Amount is than being 3：7.Coating agent is stearic acid.Corrosion inhibiter is by N, N'- di-o-tolyls thiocarbamide, potassium iodide and potassium molybdate composition, wherein
The weight ratio of N, N'- di-o-tolyl thiocarbamide, potassium iodide and potassium molybdate is 1：1：1.Sustained release agent is by polylactic acid and polyethylene glycol
20000 compositions, wherein polylactic acid and the weight ratio of PEG 20000 are 22：3.Reinforcing agent is by sodium citrate and acrylic acid group
At, wherein the weight ratio of acrylic acid and sodium citrate is 8：2.Initiator is made of tetraethylene-glycol and isocyanates,
In, the weight ratio of tetraethylene-glycol and isocyanates is 3：2.
Whole N- beta-hydroxies ethyl-3-acetic acid ethylenediamine, diethylene triamine pentacetic acid (DTPA), bigcatkin willow are added first in mixing machine
Acid, benzyltrimethylammonium chloride, choline chloride, α-sodium olefin sulfonate, neopelex, N, N'- di-o-tolyl sulphur
Urea, potassium iodide and potassium molybdate, mix 20min in mixing machine；Then it is added all in the spraying system of vulcanization bed seed-coating machine
Stearic acid, slow heating be warming up to 70 DEG C；Mixture in first time mixing machine is slowly added to vulcanization bed seed-coating machine, is formed
2mm single-sizes；After particle cooling, by particle and the whole polylactic acid of addition, PEG 20000, propylene in mixing machine
Acid and sodium citrate simultaneously mix 10min, and double screw extruder temperature is increased to 160 DEG C, by mixture in its second of mixing machine
It is added to double screw extruder feeding port, and drops evenly whole tetraethylene-glycols and isocyanates, extruder is opened and takes out very
It is spaced apart pass, through double screw extruder melting, squeezes out, cutting granulation, form the water-soluble slow-releasing type inhibition cleaning antiscale production of 3mm
Product.
Embodiment 2
A kind of increasing injection process of water injection well provided in this embodiment, its step are as follows：
A, injection well tubing and sleeve valve are opened, with well-washing truck (clear water) reacting cycle with 1 pit shaft of 700L/min well-flushings
After volume, sleeve valve is closed.
B, organic de-plugging section of 2 oil pipe internal volumes is just being squeezed into from oil pipe with 50L/min discharge capacities.
C, the activating agent slug for just squeezing into 20 oil pipe internal volumes from oil pipe with 700L/min discharge capacities, is arranged with 700L/min
Amount replaces the clear water of 25 oil pipe internal volumes.
D, all valves of water injection well are closed, water filling well pressure is kept to be reduced to water injection pressure 10~20% before measure naturally.
E, oil pipe cock and tubing valve at the top of water injection well are opened, slowly low dose is directly added into water into oil pipe in batches
Dissolubility slow-release inhibition cleaning antiscale.
G, oil pipe cock at the top of water injection well is closed, normal water filling is restored.
Wherein, organic de-plugging slug is by three macrogol ester of C8-10 aliphatic acid, propylene glycol block polyether, 1,1,3,3- tetra-
Chloro- 1,3- diphenyl disiloxane and dimethylformamide composition.In terms of the weight percent in organic de-plugging slug, C8-
Three macrogol ester weight percent of 10- aliphatic acid is 15%, and propylene glycol block polyether weight percent is 15%, 1,1,3,3-
Four chloro- 1,3- diphenyl disiloxane weight percent are 10%, and surplus is dimethyl formyl.
Wherein, activating agent slug is Aerosol OT, a- sodium olefin sulfonates, N- ethylperfluoro octyl sulphonyl
Amine second alcohol and water forms.In terms of the weight percent in activating agent slug, Aerosol OT weight percent
For 8%, α-sodium olefin sulfonate weight percent be 10%, N- ethylperfluoro octyl sulfonamide ethyl alcohol weight percent it is 3%,
Surplus is industrial water.
It is directly from water filling that slowly low dose is directly added into water-soluble slow-releasing type inhibition cleaning antiscale into oil pipe in batches
It is added by conical hopper in oil pipe at the top of well, each addition is 10kg, and addition speed is 1kg/min, and weight is added and is
300kg。
Further, in some embodiments, the inhibition of water-soluble slow-releasing type is anti-clearly for water-soluble slow-releasing type inhibition cleaning antiscale
Dirty agent is mainly grouped as by the group of following parts by weight：37 parts of de-plugging agent, 15 parts of stabilizer, 15 parts of injection agent, 5 parts of coating agent,
1 part of 5 parts of corrosion inhibiter, 35 parts of sustained release agent, 2 parts of reinforcing agent and initiator.
De-plugging agent is made of N- beta-hydroxies ethyl-3-acetic acid ethylenediamine, diethylene triamine pentacetic acid (DTPA) and salicylic acid；N- β-hydroxyl
Base ethyl-3-acetic acid ethylenediamine, diethylene triamine pentacetic acid (DTPA) and salicylic weight ratio are 20：12：5.Stabilizer is by benzyl front three
The weight ratio of ammonium chloride and choline chloride composition, benzyltrimethylammonium chloride and choline chloride is 8：7.Injection agent is by α-alkenyl
Sodium sulfonate and neopelex form, the weight ratio of α-sodium olefin sulfonate and neopelex in injection agent
It is 5：9.Coating agent is stearic acid.Corrosion inhibiter is by N, N'- di-o-tolyls thiocarbamide, potassium iodide and potassium molybdate composition, wherein N,
The weight ratio of N'- di-o-tolyls thiocarbamide, potassium iodide and potassium molybdate is 2：1.5：1.5.Sustained release agent is by polylactic acid and polyethylene glycol
20000 compositions, wherein polylactic acid and the weight ratio of PEG 20000 are 29：5.Reinforcing agent is mainly by sodium gluconate, neighbour
Phthalic acid sodium is formed with acrylic acid, wherein acrylic acid and the weight ratio of the total weight of sodium citrate and sodium phthalate are
15：5.Initiator is made of tetraethylene-glycol and isocyanates, wherein the weight ratio of tetraethylene-glycol and isocyanates is
7：3.
Whole N- beta-hydroxies ethyl-3-acetic acid ethylenediamine, diethylene triamine pentacetic acid (DTPA), bigcatkin willow are added first in mixing machine
Acid, benzyltrimethylammonium chloride, choline chloride, α-sodium olefin sulfonate, neopelex, N, N'- di-o-tolyl sulphur
Urea, potassium iodide and potassium molybdate, mix 30min in mixing machine；Then it is added all in the spraying system of vulcanization bed seed-coating machine
Stearic acid, slow heating be warming up to 72 DEG C；Mixture in first time mixing machine is slowly added to vulcanization bed seed-coating machine, is formed
3mm single-sizes；After particle cooling, by particle and the whole polylactic acid of addition, PEG 20000, propylene in mixing machine
Sour and sodium citrate, sodium phthalate simultaneously mix 15min, and double screw extruder temperature is increased to 165 DEG C, mixed by its second
Mixture is added to double screw extruder feeding port in conjunction machine, and drops evenly whole tetraethylene-glycols and isocyanates, opens
Extruder vacuum switch is opened, through double screw extruder melting, squeezes out, cutting granulation, forms the water-soluble slow-releasing type inhibition of 4mm
Cleaning antiscale product.
Embodiment 3
A kind of increasing injection process of water injection well provided in this embodiment, its step are as follows：
A, injection well tubing and sleeve valve are opened, with well-washing truck (clear water) reacting cycle with 1 pit shaft of 600L/min well-flushings
After volume, sleeve valve is closed.
B, organic de-plugging section of 1.8 oil pipe internal volumes is just being squeezed into from oil pipe with 40L/min discharge capacities.
C, the activating agent slug for just squeezing into 17 oil pipe internal volumes from oil pipe with 600L/min discharge capacities, is arranged with 600L/min
Amount replaces the clear water of 22 oil pipe internal volumes.
D, all valves of water injection well are closed, water filling well pressure is kept to be reduced to water injection pressure 15% before measure naturally.
E, oil pipe cock and tubing valve at the top of water injection well are opened, slowly low dose is directly added into water into oil pipe in batches
Dissolubility slow-release inhibition cleaning antiscale.
G, oil pipe cock at the top of water injection well is closed, normal water filling is restored.
Wherein, organic de-plugging slug is by three macrogol ester of C8-10 aliphatic acid, propylene glycol block polyether, 1,1,3,3- tetra-
Chloro- 1,3- diphenyl disiloxane and dimethylformamide composition.In terms of the weight percent in organic de-plugging slug, C8-
Three macrogol ester weight percent of 10- aliphatic acid is 13%, and propylene glycol block polyether weight percent is 13%, 1,1,3,3-
Four chloro- 1,3- diphenyl disiloxane weight percent are 8%, and surplus is dimethyl formyl.
Wherein, activating agent slug is Aerosol OT, a- sodium olefin sulfonates, N- ethylperfluoro octyl sulphonyl
Amine second alcohol and water forms.In terms of the weight percent in activating agent slug, Aerosol OT weight percent
For 7%, α-sodium olefin sulfonate weight percent be 9%, N- ethylperfluoro octyl sulfonamide ethyl alcohol weight percent it is 2.5%,
Its surplus is industrial water.
It is directly from water filling that slowly low dose is directly added into water-soluble slow-releasing type inhibition cleaning antiscale into oil pipe in batches
It is added by conical hopper in oil pipe at the top of well, each addition is 8kg, and addition speed is 0.8kg/min, and weight is added and is
250kg。
Water-soluble slow-releasing type inhibition cleaning antiscale is grouped as by the group of following parts by weight：30 parts of de-plugging agent, stabilizer 12
Part, 13 parts of injection agent, 4 parts of coating agent, 4 parts of corrosion inhibiter, 30 parts of sustained release agent, 2 parts of reinforcing agent and 0.8 part of initiator.
De-plugging agent is mainly made of N- beta-hydroxies ethyl-3-acetic acid ethylenediamine, diethylene triamine pentacetic acid (DTPA) and salicylic acid；N-
Beta-hydroxy ethyl-3-acetic acid ethylenediamine, diethylene triamine pentacetic acid (DTPA) and salicylic weight ratio are 15：9：4.Stabilizer is by benzyl
The weight ratio of trimethyl ammonium chloride and choline chloride composition, benzyltrimethylammonium chloride and choline chloride is 7：6.Injection agent is by α-
Sodium olefin sulfonate and neopelex form, the weight of α-sodium olefin sulfonate and neopelex in injection agent
Amount is than being 4：9.Coating agent is stearic acid.Corrosion inhibiter is by N, N'- di-o-tolyls thiocarbamide, potassium iodide and potassium molybdate composition, wherein
The weight ratio of N, N'- di-o-tolyl thiocarbamide, potassium iodide and potassium molybdate is 1.5：1.2：1.2.Sustained release agent mainly by polylactic acid and
PEG 20000 forms, wherein polylactic acid and the weight ratio of PEG 20000 are 27：4.Reinforcing agent is by phthalic acid
Sodium is formed with acrylic acid, wherein the weight ratio of acrylic acid and sodium phthalate is 10：3.Initiator by tetraethylene-glycol and
Isocyanates forms, wherein the weight ratio of tetraethylene-glycol and isocyanates is 5：2.
Whole N- beta-hydroxies ethyl-3-acetic acid ethylenediamine, diethylene triamine pentacetic acid (DTPA), bigcatkin willow are added first in mixing machine
Acid, benzyltrimethylammonium chloride, choline chloride, α-sodium olefin sulfonate, neopelex, N, N'- di-o-tolyl sulphur
Urea, potassium iodide and potassium molybdate mix 20~30min in mixing machine；Then it is added in the spraying system of vulcanization bed seed-coating machine
Whole stearic acid, slow heating are warming up to 71 DEG C；Mixture in first time mixing machine is slowly added to vulcanization bed seed-coating machine, shape
At 3mm single-sizes；After particle cooling, by particle and the whole polylactic acid of addition, PEG 20000, third in mixing machine
Olefin(e) acid and sodium phthalate simultaneously mix 12min, and double screw extruder temperature is increased to 163 DEG C, will be in its second of mixing machine
Mixture is added to double screw extruder feeding port, and drops evenly whole tetraethylene-glycols and isocyanates, opens and squeezes out
Machine vacuum switch through double screw extruder melting, squeezes out, cutting granulation, forms the clear antiscale of water-soluble slow-releasing type inhibition of 4mm
Agent product.
Embodiment 4
A kind of increasing injection process of water injection well provided in this embodiment, includes the following steps：
The first step：Injection well tubing and sleeve valve are opened, is washed with 500L/min discharge capacities with well-washing truck (clear water) reacting cycle
After 1 hole volume of well, sleeve valve is closed.
Second step：The C8-10- fat that weight percent is 15% is added in the organic de-plugging slug of extemporaneous preparation in big tank
Sour three macrogol esters, the propylene glycol block polyether that weight percent is 10%, weight percent are 1, the 1,3,3- tetra- of 5%
Chloro- 1,3- diphenyl disiloxane, the dimethyl formyl that weight percent is 70%, uses cementing truck cycle balance.
Third walks：Extemporaneous preparation activating agent slug, it is 8% succinic acid di-isooctyl sulphur that weight percent is added in big tank
Sour sodium, α-sodium olefin sulfonate that weight percent is 10%, the N- ethylperfluoro octyl sulfonamide second that weight percent is 2%
Alcohol, weight percent are 80% industrial water, use cementing truck cycle balance.
4th step：With high-pressure plunger pump (junction the be hard sealing) equipment with check valve with 30L/min discharge capacities from oil
Pipe is just squeezing into organic de-plugging slug of 2 oil pipe internal volumes.
5th step：20 oil pipe internal volumes are just being squeezed into 500L/min discharge capacities from oil pipe with 700 type cement vehicle devices
Activating agent slug, while with the clear water of 500L/min discharge capacities 20 oil pipe internal volumes of replacement.
6th step：All valves of water injection well are closed, are noted before making water injection well pressure reduction to measure by pressure natural diffuseness
Water pressure 15%.
7th step：Open oil pipe cock and tubing valve at the top of water injection well.
8th step：By conical hopper with every batch of addition it is 5kg in oil pipe at the top of water injection well, speed, which is added, is
300kg water-soluble slow-releasing type inhibition cleaning antiscales are added in 1kg/min.The preparation of water-soluble slow-releasing type inhibition cleaning antiscale and system
For referring to embodiment 3.
9th step：Oil pipe cock at the top of water injection well is closed, normal water filling is restored.
Embodiment 5
The present embodiment is by taking 2000 meters of water injection well increasing injections as an example, water injection pressure 18MPa.
The first step：Injection well tubing and sleeve valve are opened, is washed with 700L/min discharge capacities with well-washing truck (clear water) reacting cycle
Well 22m3After clear water, sleeve valve is closed.
Second step：Extemporaneous preparation 9m3The C8-10- fat that weight percent is 10% is added in organic de-plugging slug in big tank
Fat three macrogol esters of acid, the propylene glycol block polyether that weight percent is 15%, weight percent are the 1,1,3,3- of 10%
Four chloro- 1,3- diphenyl disiloxane, the dimethyl formyl that weight percent is 65%, use cementing truck cycle balance.
Third walks：Extemporaneous preparation 90m3Activating agent slug, it is that 8% succinic acid two is different pungent that weight percent is added in big tank
Ester sodium sulfonate, weight percent are 10% α-sodium olefin sulfonates, and weight percent is 2%N- ethylperfluoro octyl sulfonamide second
Alcohol, weight percent are 80% industrial water, use cementing truck cycle balance.
4th step：With high-pressure plunger pump (junction the be hard sealing) equipment with check valve with 50L/min discharge capacities from oil
Pipe just squeezes into 9m3Organic de-plugging slug.
5th step：90m is just squeezed into from oil pipe with 700L/min discharge capacities with 700 type cement vehicle devices3Activating agent slug, together
When with 700L/min discharge capacities replace 150m3Clear water.
6th step：All valves of water injection well are closed, pressure waits for water injection well pressure reduction to 3.5Mpa by natural diffuseness.
7th step：Open oil pipe cock and tubing valve at the top of water injection well.
8th step：By conical hopper with every batch of addition it is 10kg in oil pipe at the top of water injection well, speed, which is added, is
150kg water-soluble slow-releasing type inhibition cleaning antiscales are added in 0.5kg/min.The preparation of water-soluble slow-releasing type inhibition cleaning antiscale and
It prepares referring to embodiment 3.
9th step：Oil pipe cock at the top of water injection well is closed, normal water filling is restored.
Embodiment 6
By taking 1500 meters of water injection well increasing injections as an example, water injection pressure 17MPa.
The first step：Injection well tubing and sleeve valve are opened, is washed with 600L/min discharge capacities with well-washing truck (clear water) reacting cycle
Well 16.5m3After clear water, sleeve valve is closed.
Second step：Extemporaneous preparation 8m3The C8-10- fat that weight percent is 12% is added in organic de-plugging slug in big tank
Fat three macrogol esters of acid, the propylene glycol block polyether that weight percent is 12%, weight percent are 1, the 1,3,3- tetra- of 8%
Chloro- 1,3- diphenyl disiloxane, the dimethyl formyl that weight percent is 6%, uses cementing truck cycle balance.
Third walks：Extemporaneous preparation 80m3Activating agent slug, it is that 6% succinic acid two is different pungent that weight percent is added in big tank
Ester sodium sulfonate, weight percent are 9% α-sodium olefin sulfonates, and weight percent is 2.5%N- ethylperfluoro octyl sulfonamide second
Alcohol, weight percent are 82.5% industrial water, use cementing truck cycle balance.
4th step：With high-pressure plunger pump (junction the be hard sealing) equipment with check valve with 50L/min discharge capacities from oil
Pipe just squeezes into 8m3Organic de-plugging slug.
5th step：80m is just squeezed into from oil pipe with 700L/min discharge capacities with 700 type cement vehicle devices3Activating agent slug, together
When with 700L/min discharge capacities replace 100m3Clear water.
6th step：All valves of water injection well are closed, pressure waits for water injection well pressure reduction to 2Mpa by natural diffuseness.
7th step：Open oil pipe cock and tubing valve at the top of water injection well.
8th step：By conical hopper with every batch of addition it is 8kg in oil pipe at the top of water injection well, speed, which is added, is
200kg water-soluble slow-releasing type inhibition cleaning antiscales are added in 0.75kg/min.The preparation of water-soluble slow-releasing type inhibition cleaning antiscale and
It prepares referring to embodiment 3.
9th step：Oil pipe cock at the top of water injection well is closed, normal water filling is restored.
Embodiment 7
It the difference is that only the present embodiment compared with Example 3, does not carry out reacting cycle clear water and washes water injection well.
Embodiment 8
The present embodiment difference from Example 3 is only that, unimplanted water-soluble slow-releasing type inhibition cleaning antiscale.
Comparative example 1
This comparative example difference from Example 3 is only that organic de-plugging slug only contains C8-10- aliphatic acid trimerization second
Diol ester and propylene glycol block polyether；Activating agent slug only contains Aerosol OT, α-sodium olefin sulfonate and water.
Test example
It will be tested in practical water injection well according to the method for Examples 1 to 8 and comparative example 1, pound sign is distinguished successively
For J200-38, J207-42, J205-41, J202-39, X28-46, X34-58, X35-59, X36-61, X37-63.And to correlation
Data measure acquisition, and the results are shown in Table 1.
1 water injection well increasing injection measure effect of table
The method in the embodiment of the present invention is can be seen that by result in table to be applied to play preferably in live water injection well
Increasing injection effect, and the duration is longer.From the comparison of embodiment 3 and embodiment 7-8, it can be seen that clear water recoils
It washes and injects water-soluble slow-releasing type inhibition cleaning antiscale and be conducive to enhance the effect of increasing injection and extend the expiration date.Pass through
The comparison of comparative example and embodiment 3 as can be seen that organic de-plugging slug and activating agent slug at component selections to increasing injection
Effect has large effect.
In conclusion its mating pharmaceutical chemistry property of the method for embodiment of the present invention reduces flow string and removes, drop
Low labor intensity, has saved measure cost；The technique of construction plays medicament function and effect in reservoir to greatest extent, improves
The job safety feature of environmental protection；The long-term effect of especially mating medicament such as water-soluble slow-releasing type inhibition cleaning antiscale, avoids medicament more
Secondary addition reduces workover treatment frequency, saves oil field and integrates production cost.
Embodiments described above is a part of the embodiment of the present invention, instead of all the embodiments.The reality of the present invention
The detailed description for applying example is not intended to limit the range of claimed invention, but is merely representative of the selected implementation of the present invention
Example.Based on the embodiments of the present invention, those of ordinary skill in the art are obtained without creative efforts
Every other embodiment, shall fall within the protection scope of the present invention.
Claims (10)
1. a kind of increasing injection process of water injection well, which is characterized in that it includes the following steps：
Organic de-plugging slug is just being squeezed into from oil pipe；
Again by activating agent slug after the oil pipe just squeezes into, then replacement clear water just squeezed by the oil pipe, by institute
It states machine de-plugging slug and the activating agent slug pushes to distal end；
All valves of water injection well are closed, so that water filling well pressure is reduced to water filling before just squeezing into organic de-plugging slug naturally
The 10%~20% of pressure；
Wherein, organic de-plugging slug is mainly by three macrogol ester of C8-10- aliphatic acid, propylene glycol block polyether, 1, and 1,3,
Tetra- chloro- 1,3- diphenyl disiloxane of 3- and dimethylformamide composition；
The activating agent slug is mainly by Aerosol OT, α-sodium olefin sulfonate, N- ethylperfluoro octyl sulphonyl
Amine second alcohol and water forms.
2. the increasing injection process of water injection well according to claim 1, which is characterized in that organic de-plugging slug
In, the weight percent of three macrogol ester of C8-10- aliphatic acid is 10~15%, the weight of the propylene glycol block polyether
Amount percentage is that the weight percent of 10~15%, described 1,1,3,3- tetra- chloro- 1,3- diphenyl disiloxane is 5~10%,
Surplus is the dimethyl formyl.
3. the increasing injection process of water injection well according to claim 1, in the activating agent slug, the succinic acid
The weight percent of di-isooctyl sodium sulfonate is 5~8%, and the weight percent of the α-sodium olefin sulfonate is 8~10%, described
The weight percent of N- ethylperfluoro octyl sulfonamide ethyl alcohol is 2~3%, and surplus is water.
4. the increasing injection process of water injection well according to claim 1, which is characterized in that by organic de-plugging section
It is 30L/min-50L/min to fill in the discharge capacity just squeezed into from the oil pipe, and total dosage of preferably described organic de-plugging slug is 1.5
~2 oil pipe internal volumes；
The discharge capacity that the activating agent slug is just being squeezed into from the oil pipe is 500L/min-700L/min, the preferably described activity
Total dosage of agent slug is 15~20 oil pipe internal volumes.
5. the increasing injection process of water injection well according to claim 1, which is characterized in that inject the replacement clear water
Discharge capacity be 500L/min-700L/min, preferably it is described replace clear water total dosage be 20~25 oil pipe internal volumes.
6. the increasing injection process of water injection well according to claim 1, which is characterized in that injecting organic solution
Before stifled slug, by clear water reacting cycle well-flushing, the discharge capacity of the clear water of reacting cycle well-flushing is 500L/min-700L/min, excellent
It is 0.8~2 hole volume to select total dosage of the clear water of reacting cycle well-flushing.
7. according to the increasing injection process of claim 1~6 any one of them water injection well, which is characterized in that the note
The increasing injection process of well further includes：Before the water filling well pressure is reduced to measure naturally the 10% of water injection pressure~
After 20%, oil pipe cock and tubing valve at the top of the water injection well are opened, water-soluble slow-releasing type inhibition is injected by the oil pipe
Cleaning antiscale.
8. the increasing injection process of water injection well according to claim 7, which is characterized in that the water-soluble slow-releasing type
Inhibition cleaning antiscale is mainly grouped as by the group of following parts by weight：20~37 parts of de-plugging agent, 10~15 parts of stabilizer, injection agent
10~15 parts, 3~5 parts of coating agent, 3~5 parts of corrosion inhibiter, 25~35 parts of sustained release agent, 1~2 part of reinforcing agent and initiator 0.5~
1 part.
9. the increasing injection process of water injection well according to claim 8, which is characterized in that the de-plugging agent mainly by
N- beta-hydroxies ethyl-3-acetic acid ethylenediamine, diethylene triamine pentacetic acid (DTPA) and salicylic acid composition；The N- beta-hydroxies ethylethylenediamine
Triacetic acid, the diethylene triamine pentacetic acid (DTPA) and the salicylic weight ratio are 10~20：7~12：3~5；
Preferably, the stabilizer is mainly made of benzyltrimethylammonium chloride and choline chloride, it is further preferred that the benzyl
The weight ratio of base trimethyl ammonium chloride and the choline chloride is 5~8：5~7；
Preferably, the injection agent is mainly made of α-sodium olefin sulfonate and neopelex, it is further preferred that institute
The weight ratio for stating the α-sodium olefin sulfonate and the neopelex in injection agent is 3~5：7~10；
Preferably, the coating agent is stearic acid；
Preferably, corrosion inhibiter is mainly by N, N'- di-o-tolyls thiocarbamide, potassium iodide and potassium molybdate composition, wherein the N, N'-
The weight ratio of di-o-tolyl thiocarbamide, the potassium iodide and the potassium molybdate is 1~2：1~1.5：1~1.5；
Preferably, the sustained release agent is mainly made of polylactic acid and PEG 20000, wherein the polylactic acid and described poly-
The weight ratio of ethylene glycol 20000 is 22~30：3~5；
Preferably, the reinforcing agent is mainly by one or more with third in sodium citrate, sodium gluconate, sodium phthalate
Olefin(e) acid forms, wherein the acrylic acid and one in the sodium citrate, the sodium gluconate, the sodium phthalate
Kind or a variety of weight ratios are 8~15：2~5；
Preferably, the initiator is mainly made of tetraethylene-glycol and isocyanates, wherein the tetraethylene-glycol and
The weight ratio of the isocyanates is 3~7：2~3.
10. a kind of increasing injection process of water injection well as claimed in any one of claims 1 to 9 wherein is in tight sandstone reservoir
The application that stake initial stage high pressure is shorted.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201810929411.7A CN108775236B (en) | 2018-08-15 | 2018-08-15 | Pressure-reducing and injection-increasing process method for water injection well and application thereof |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201810929411.7A CN108775236B (en) | 2018-08-15 | 2018-08-15 | Pressure-reducing and injection-increasing process method for water injection well and application thereof |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN108775236A true CN108775236A (en) | 2018-11-09 |
| CN108775236B CN108775236B (en) | 2020-06-26 |
Family
ID=64028798
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201810929411.7A Active CN108775236B (en) | 2018-08-15 | 2018-08-15 | Pressure-reducing and injection-increasing process method for water injection well and application thereof |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN108775236B (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN112251203A (en) * | 2020-09-27 | 2021-01-22 | 中国石油天然气股份有限公司 | Microemulsion blocking remover suitable for ultra-low permeability reservoir, preparation method thereof and pressure-reducing injection-increasing method |
Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN103573235A (en) * | 2013-11-01 | 2014-02-12 | 中国石油集团川庆钻探工程有限公司 | Acidizing, pressure-decreasing and injection-increasing technique without replacing string for water injection well |
| CN103642478A (en) * | 2013-11-27 | 2014-03-19 | 中国石油天然气股份有限公司 | Blocking remover for removing polymer pollutants |
| CN105985759A (en) * | 2015-02-11 | 2016-10-05 | 中国海洋石油总公司 | Composite blocking remover for oil well and preparation method thereof |
| CN106085401A (en) * | 2016-06-07 | 2016-11-09 | 郑州东申石化科技有限公司 | A kind of water injection in low-permeability oilfield well increasing injection agent and preparation method and application |
| CN107384352A (en) * | 2017-06-28 | 2017-11-24 | 常州市雄图纺织有限公司 | A kind of de-plugging agent and its application method |
-
2018
- 2018-08-15 CN CN201810929411.7A patent/CN108775236B/en active Active
Patent Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN103573235A (en) * | 2013-11-01 | 2014-02-12 | 中国石油集团川庆钻探工程有限公司 | Acidizing, pressure-decreasing and injection-increasing technique without replacing string for water injection well |
| CN103642478A (en) * | 2013-11-27 | 2014-03-19 | 中国石油天然气股份有限公司 | Blocking remover for removing polymer pollutants |
| CN105985759A (en) * | 2015-02-11 | 2016-10-05 | 中国海洋石油总公司 | Composite blocking remover for oil well and preparation method thereof |
| CN106085401A (en) * | 2016-06-07 | 2016-11-09 | 郑州东申石化科技有限公司 | A kind of water injection in low-permeability oilfield well increasing injection agent and preparation method and application |
| CN107384352A (en) * | 2017-06-28 | 2017-11-24 | 常州市雄图纺织有限公司 | A kind of de-plugging agent and its application method |
Non-Patent Citations (1)
| Title |
|---|
| 雷金华等: "低渗透油藏注表面活性剂协同酸化解堵降压增注研究", 《工程研究——跨学科视野中的工程》 * |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN112251203A (en) * | 2020-09-27 | 2021-01-22 | 中国石油天然气股份有限公司 | Microemulsion blocking remover suitable for ultra-low permeability reservoir, preparation method thereof and pressure-reducing injection-increasing method |
Also Published As
| Publication number | Publication date |
|---|---|
| CN108775236B (en) | 2020-06-26 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN102076809B (en) | Method for changing wettability of rock formations | |
| CN105089596B (en) | A kind of hydraulic fracturing remodeling method of unconventional reservoir oil/gas well | |
| CN102746838B (en) | Blocking remover of gas well shaft | |
| CN103396774B (en) | Sealing agent and preparation method thereof | |
| CN103965844B (en) | Low-density microvesicle workover fluid | |
| CN106050213B (en) | A kind of sandstone reservoir low damage distributary acid method | |
| CN103321606B (en) | A kind of Fracture with low permeability oil reservoir oilwell water shutoff screen method | |
| CN105985759A (en) | Composite blocking remover for oil well and preparation method thereof | |
| BR112016013465B1 (en) | PROCESS FOR PRODUCING MINERAL OIL, WATER-SOLUBLE COPOLYMER AND AQUEOUS FORMULATION | |
| CN104293333A (en) | Neutral blocking remover composition for oilfield oil extraction and preparation method thereof | |
| CN103328602A (en) | Method for oil recovery using hydrophobically associating polymers | |
| CN103328601A (en) | Aqueous formulations of hydrophobically associating copolymers and surfactants and also their use for pertroleum recovery | |
| EA002585B1 (en) | Fluids and techniques for hydrocarbon well completion | |
| CN101323780A (en) | Low pervasion oilfield thermochemical cleanup additive and use thereof | |
| CN104109514B (en) | A kind of sealing agent system for permanent closure multilamellar low pressure macropore oil reservoir and Technology | |
| CN104099074B (en) | Volume fracturing reconstruction crack plugging agent and water plugging construction method | |
| BRPI0809395A2 (en) | method of treatment of underground formations by in situ hydrolysis of organic acid esters | |
| CN106867486A (en) | A kind of frothy gel well workover method for increasing made with water blockoff connection and its application | |
| CN110905460B (en) | Viscosity-reducing foaming exploitation method for common heavy oil reservoir | |
| CN105649594A (en) | Method for maintaining flow conductivity of seams near wellbore area | |
| CN105960505A (en) | Methods of pre-flushing reservoir paths for higher return of hydrocarbon fluids | |
| CN105733533A (en) | Acid soluble mineral fiber fine bridging agent, bridging fluid and preparation method thereof | |
| CN103740340A (en) | Expansion and solidification type plugging agent | |
| CN105733532A (en) | Acid soluble mineral fiber medium-coarse bridging agent, bridging fluid and preparation method thereof | |
| CN109915093A (en) | A kind of method that " stifled/tune/drive " integration improves oil recovery |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |