CN115746810B - Anti-wetting active blocking remover applicable to low-permeability high-clay-content oil reservoir - Google Patents
Anti-wetting active blocking remover applicable to low-permeability high-clay-content oil reservoir Download PDFInfo
- Publication number
- CN115746810B CN115746810B CN202211467802.4A CN202211467802A CN115746810B CN 115746810 B CN115746810 B CN 115746810B CN 202211467802 A CN202211467802 A CN 202211467802A CN 115746810 B CN115746810 B CN 115746810B
- Authority
- CN
- China
- Prior art keywords
- acrylamide
- parts
- blocking remover
- oil reservoir
- wetting
- 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.)
- Active
Links
- 230000000903 blocking effect Effects 0.000 title claims abstract description 52
- 238000009736 wetting Methods 0.000 title claims abstract description 44
- HRPVXLWXLXDGHG-UHFFFAOYSA-N Acrylamide Chemical compound NC(=O)C=C HRPVXLWXLXDGHG-UHFFFAOYSA-N 0.000 claims abstract description 39
- 229920006322 acrylamide copolymer Polymers 0.000 claims abstract description 39
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 32
- 239000004094 surface-active agent Substances 0.000 claims abstract description 26
- 229910019142 PO4 Inorganic materials 0.000 claims abstract description 21
- 239000010452 phosphate Substances 0.000 claims abstract description 21
- NBIIXXVUZAFLBC-UHFFFAOYSA-K phosphate Chemical compound [O-]P([O-])([O-])=O NBIIXXVUZAFLBC-UHFFFAOYSA-K 0.000 claims abstract description 21
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 claims abstract description 21
- 239000003208 petroleum Substances 0.000 claims abstract description 17
- XMGQYMWWDOXHJM-UHFFFAOYSA-N limonene Chemical compound CC(=C)C1CCC(C)=CC1 XMGQYMWWDOXHJM-UHFFFAOYSA-N 0.000 claims abstract description 14
- 235000014113 dietary fatty acids Nutrition 0.000 claims abstract description 12
- 239000000194 fatty acid Substances 0.000 claims abstract description 12
- 229930195729 fatty acid Natural products 0.000 claims abstract description 12
- 150000004665 fatty acids Chemical class 0.000 claims abstract description 12
- 239000000178 monomer Substances 0.000 claims abstract description 10
- 125000002887 hydroxy group Chemical group [H]O* 0.000 claims abstract description 9
- 125000003396 thiol group Chemical class [H]S* 0.000 claims abstract description 8
- 229940087305 limonene Drugs 0.000 claims abstract description 7
- 235000001510 limonene Nutrition 0.000 claims abstract description 7
- 239000002994 raw material Substances 0.000 claims abstract description 3
- 238000002360 preparation method Methods 0.000 claims description 24
- 239000003795 chemical substances by application Substances 0.000 claims description 15
- 238000011084 recovery Methods 0.000 claims description 15
- -1 mercaptoacetyl acrylamide Chemical group 0.000 claims description 10
- 238000003756 stirring Methods 0.000 claims description 10
- 238000005406 washing Methods 0.000 claims description 9
- 238000002156 mixing Methods 0.000 claims description 7
- 230000035699 permeability Effects 0.000 claims description 7
- 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
- 239000002253 acid Substances 0.000 claims description 6
- 238000006243 chemical reaction Methods 0.000 claims description 6
- 239000003999 initiator Substances 0.000 claims description 6
- 125000005358 mercaptoalkyl group Chemical group 0.000 claims description 6
- 239000000203 mixture Substances 0.000 claims description 6
- 239000011734 sodium Substances 0.000 claims description 6
- 229910052708 sodium Inorganic materials 0.000 claims description 6
- CWERGRDVMFNCDR-UHFFFAOYSA-N thioglycolic acid Chemical compound OC(=O)CS CWERGRDVMFNCDR-UHFFFAOYSA-N 0.000 claims description 6
- 238000001035 drying Methods 0.000 claims description 5
- GHVNFZFCNZKVNT-UHFFFAOYSA-N decanoic acid Chemical compound CCCCCCCCCC(O)=O GHVNFZFCNZKVNT-UHFFFAOYSA-N 0.000 claims description 4
- DNTMQTKDNSEIFO-UHFFFAOYSA-N n-(hydroxymethyl)-2-methylprop-2-enamide Chemical compound CC(=C)C(=O)NCO DNTMQTKDNSEIFO-UHFFFAOYSA-N 0.000 claims description 4
- 230000001105 regulatory effect Effects 0.000 claims description 4
- CNCOEDDPFOAUMB-UHFFFAOYSA-N N-Methylolacrylamide Chemical compound OCNC(=O)C=C CNCOEDDPFOAUMB-UHFFFAOYSA-N 0.000 claims description 3
- 239000012298 atmosphere Substances 0.000 claims description 3
- XAEFZNCEHLXOMS-UHFFFAOYSA-M potassium benzoate Chemical compound [K+].[O-]C(=O)C1=CC=CC=C1 XAEFZNCEHLXOMS-UHFFFAOYSA-M 0.000 claims description 3
- DKIDEFUBRARXTE-UHFFFAOYSA-N 3-mercaptopropanoic acid Chemical compound OC(=O)CCS DKIDEFUBRARXTE-UHFFFAOYSA-N 0.000 claims description 2
- 239000005632 Capric acid (CAS 334-48-5) Substances 0.000 claims description 2
- 238000010438 heat treatment Methods 0.000 claims description 2
- 238000000034 method Methods 0.000 claims description 2
- UUORTJUPDJJXST-UHFFFAOYSA-N n-(2-hydroxyethyl)prop-2-enamide Chemical compound OCCNC(=O)C=C UUORTJUPDJJXST-UHFFFAOYSA-N 0.000 claims description 2
- IPGRTXQKFZCLJS-UHFFFAOYSA-N n-(2-hydroxypropyl)prop-2-enamide Chemical compound CC(O)CNC(=O)C=C IPGRTXQKFZCLJS-UHFFFAOYSA-N 0.000 claims description 2
- MVBJSQCJPSRKSW-UHFFFAOYSA-N n-[1,3-dihydroxy-2-(hydroxymethyl)propan-2-yl]prop-2-enamide Chemical compound OCC(CO)(CO)NC(=O)C=C MVBJSQCJPSRKSW-UHFFFAOYSA-N 0.000 claims description 2
- 229950007031 palmidrol Drugs 0.000 claims description 2
- HXYVTAGFYLMHSO-UHFFFAOYSA-N palmitoyl ethanolamide Chemical compound CCCCCCCCCCCCCCCC(=O)NCCO HXYVTAGFYLMHSO-UHFFFAOYSA-N 0.000 claims description 2
- 238000006116 polymerization reaction Methods 0.000 claims description 2
- 159000000000 sodium salts Chemical group 0.000 claims description 2
- 150000003926 acrylamides Chemical class 0.000 claims 3
- WBYWAXJHAXSJNI-VOTSOKGWSA-M .beta-Phenylacrylic acid Natural products [O-]C(=O)\C=C\C1=CC=CC=C1 WBYWAXJHAXSJNI-VOTSOKGWSA-M 0.000 claims 1
- WBYWAXJHAXSJNI-SREVYHEPSA-N Cinnamic acid Chemical compound OC(=O)\C=C/C1=CC=CC=C1 WBYWAXJHAXSJNI-SREVYHEPSA-N 0.000 claims 1
- ZLMJMSJWJFRBEC-UHFFFAOYSA-N Potassium Chemical compound [K] ZLMJMSJWJFRBEC-UHFFFAOYSA-N 0.000 claims 1
- 229930016911 cinnamic acid Natural products 0.000 claims 1
- 235000013985 cinnamic acid Nutrition 0.000 claims 1
- WBYWAXJHAXSJNI-UHFFFAOYSA-N methyl p-hydroxycinnamate Natural products OC(=O)C=CC1=CC=CC=C1 WBYWAXJHAXSJNI-UHFFFAOYSA-N 0.000 claims 1
- 229910052700 potassium Inorganic materials 0.000 claims 1
- 239000011591 potassium Substances 0.000 claims 1
- 239000011435 rock Substances 0.000 abstract description 17
- 238000005213 imbibition Methods 0.000 abstract description 15
- 230000000694 effects Effects 0.000 abstract description 13
- 229920006317 cationic polymer Polymers 0.000 abstract description 11
- 238000006073 displacement reaction Methods 0.000 abstract description 5
- 230000002269 spontaneous effect Effects 0.000 abstract description 4
- 230000002195 synergetic effect Effects 0.000 abstract description 2
- 239000003921 oil Substances 0.000 description 49
- 239000004927 clay Substances 0.000 description 25
- 239000000243 solution Substances 0.000 description 18
- 230000000052 comparative effect Effects 0.000 description 15
- 239000010779 crude oil Substances 0.000 description 15
- 230000036571 hydration Effects 0.000 description 13
- 238000006703 hydration reaction Methods 0.000 description 13
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 description 12
- 238000012360 testing method Methods 0.000 description 12
- 230000008961 swelling Effects 0.000 description 10
- 238000004519 manufacturing process Methods 0.000 description 9
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 8
- 239000011148 porous material Substances 0.000 description 8
- 230000002829 reductive effect Effects 0.000 description 7
- 239000006004 Quartz sand Substances 0.000 description 6
- 239000000440 bentonite Substances 0.000 description 6
- 229910000278 bentonite Inorganic materials 0.000 description 6
- SVPXDRXYRYOSEX-UHFFFAOYSA-N bentoquatam Chemical compound O.O=[Si]=O.O=[Al]O[Al]=O SVPXDRXYRYOSEX-UHFFFAOYSA-N 0.000 description 6
- 230000002579 anti-swelling effect Effects 0.000 description 5
- 229920001577 copolymer Polymers 0.000 description 5
- 229910052500 inorganic mineral Inorganic materials 0.000 description 5
- 239000011707 mineral Substances 0.000 description 5
- 235000010755 mineral Nutrition 0.000 description 5
- 230000003204 osmotic effect Effects 0.000 description 5
- 230000002411 adverse Effects 0.000 description 4
- ROOXNKNUYICQNP-UHFFFAOYSA-N ammonium persulfate Chemical compound [NH4+].[NH4+].[O-]S(=O)(=O)OOS([O-])(=O)=O ROOXNKNUYICQNP-UHFFFAOYSA-N 0.000 description 4
- 238000011161 development Methods 0.000 description 4
- 239000003129 oil well Substances 0.000 description 4
- 238000011056 performance test Methods 0.000 description 4
- 230000035945 sensitivity Effects 0.000 description 4
- 235000015170 shellfish Nutrition 0.000 description 4
- 238000005303 weighing Methods 0.000 description 4
- 241000193830 Bacillus <bacterium> Species 0.000 description 3
- QZXSMBBFBXPQHI-UHFFFAOYSA-N N-(dodecanoyl)ethanolamine Chemical compound CCCCCCCCCCCC(=O)NCCO QZXSMBBFBXPQHI-UHFFFAOYSA-N 0.000 description 3
- KWYUFKZDYYNOTN-UHFFFAOYSA-M Potassium hydroxide Chemical compound [OH-].[K+] KWYUFKZDYYNOTN-UHFFFAOYSA-M 0.000 description 3
- 239000003945 anionic surfactant Substances 0.000 description 3
- 230000008859 change Effects 0.000 description 3
- 239000002734 clay mineral Substances 0.000 description 3
- 238000002474 experimental method Methods 0.000 description 3
- 230000002209 hydrophobic effect Effects 0.000 description 3
- 230000002401 inhibitory effect Effects 0.000 description 3
- 230000007774 longterm Effects 0.000 description 3
- 239000000693 micelle Substances 0.000 description 3
- IJGRMHOSHXDMSA-UHFFFAOYSA-N nitrogen Substances N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 3
- 229920006395 saturated elastomer Polymers 0.000 description 3
- CSCPPACGZOOCGX-UHFFFAOYSA-N Acetone Chemical compound CC(C)=O CSCPPACGZOOCGX-UHFFFAOYSA-N 0.000 description 2
- XKRFYHLGVUSROY-UHFFFAOYSA-N Argon Chemical compound [Ar] XKRFYHLGVUSROY-UHFFFAOYSA-N 0.000 description 2
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 description 2
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical compound [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 description 2
- DWAQJAXMDSEUJJ-UHFFFAOYSA-M Sodium bisulfite Chemical compound [Na+].OS([O-])=O DWAQJAXMDSEUJJ-UHFFFAOYSA-M 0.000 description 2
- 229910001870 ammonium persulfate Inorganic materials 0.000 description 2
- 150000001768 cations Chemical class 0.000 description 2
- 239000000084 colloidal system Substances 0.000 description 2
- 238000010276 construction Methods 0.000 description 2
- 239000011258 core-shell material Substances 0.000 description 2
- 239000013078 crystal Substances 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 230000002708 enhancing effect Effects 0.000 description 2
- NBVXSUQYWXRMNV-UHFFFAOYSA-N fluoromethane Chemical compound FC NBVXSUQYWXRMNV-UHFFFAOYSA-N 0.000 description 2
- 239000008398 formation water Substances 0.000 description 2
- 239000007789 gas Substances 0.000 description 2
- 238000000227 grinding Methods 0.000 description 2
- 238000002347 injection Methods 0.000 description 2
- 239000007924 injection Substances 0.000 description 2
- 239000007788 liquid Substances 0.000 description 2
- 229910052757 nitrogen Inorganic materials 0.000 description 2
- 230000000149 penetrating effect Effects 0.000 description 2
- 229920000642 polymer Polymers 0.000 description 2
- 239000000047 product Substances 0.000 description 2
- 238000002791 soaking Methods 0.000 description 2
- 235000010267 sodium hydrogen sulphite Nutrition 0.000 description 2
- FWFUWXVFYKCSQA-UHFFFAOYSA-M sodium;2-methyl-2-(prop-2-enoylamino)propane-1-sulfonate Chemical compound [Na+].[O-]S(=O)(=O)CC(C)(C)NC(=O)C=C FWFUWXVFYKCSQA-UHFFFAOYSA-M 0.000 description 2
- 238000001179 sorption measurement Methods 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- 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 description 1
- CFPHMAVQAJGVPV-UHFFFAOYSA-N 2-sulfanylbutanoic acid Chemical compound CCC(S)C(O)=O CFPHMAVQAJGVPV-UHFFFAOYSA-N 0.000 description 1
- LSNNMFCWUKXFEE-UHFFFAOYSA-M Bisulfite Chemical compound OS([O-])=O LSNNMFCWUKXFEE-UHFFFAOYSA-M 0.000 description 1
- 229920000742 Cotton Polymers 0.000 description 1
- 238000010521 absorption reaction Methods 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 125000002252 acyl group Chemical group 0.000 description 1
- 239000003513 alkali Substances 0.000 description 1
- 125000000129 anionic group Chemical group 0.000 description 1
- 239000007864 aqueous solution Substances 0.000 description 1
- 229910052786 argon Inorganic materials 0.000 description 1
- 159000000009 barium salts Chemical class 0.000 description 1
- 238000003287 bathing Methods 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000003876 biosurfactant Substances 0.000 description 1
- 159000000007 calcium salts Chemical class 0.000 description 1
- 239000003054 catalyst Substances 0.000 description 1
- 239000003093 cationic surfactant Substances 0.000 description 1
- 239000003153 chemical reaction reagent Substances 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 229940071160 cocoate Drugs 0.000 description 1
- 238000013329 compounding Methods 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 230000008878 coupling Effects 0.000 description 1
- 238000010168 coupling process Methods 0.000 description 1
- 238000005859 coupling reaction Methods 0.000 description 1
- 230000008021 deposition 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
- 238000010790 dilution Methods 0.000 description 1
- 239000012895 dilution Substances 0.000 description 1
- RXCBCUJUGULOGC-UHFFFAOYSA-H dipotassium;tetrafluorotitanium;difluoride Chemical compound [F-].[F-].[F-].[F-].[F-].[F-].[K+].[K+].[Ti+4] RXCBCUJUGULOGC-UHFFFAOYSA-H 0.000 description 1
- 238000007598 dipping method Methods 0.000 description 1
- 238000000855 fermentation Methods 0.000 description 1
- 230000004151 fermentation Effects 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 229910052900 illite Inorganic materials 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- 230000005764 inhibitory process Effects 0.000 description 1
- 230000010354 integration Effects 0.000 description 1
- NLYAJNPCOHFWQQ-UHFFFAOYSA-N kaolin Chemical compound O.O.O=[Al]O[Si](=O)O[Si](=O)O[Al]=O NLYAJNPCOHFWQQ-UHFFFAOYSA-N 0.000 description 1
- 229910052622 kaolinite Inorganic materials 0.000 description 1
- 239000003350 kerosene Substances 0.000 description 1
- 159000000003 magnesium salts Chemical class 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 229910052751 metal Inorganic materials 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- 229910021645 metal ion Inorganic materials 0.000 description 1
- 229910052901 montmorillonite Inorganic materials 0.000 description 1
- 239000005543 nano-size silicon particle Substances 0.000 description 1
- 230000007935 neutral effect Effects 0.000 description 1
- 230000003472 neutralizing effect Effects 0.000 description 1
- 239000012299 nitrogen atmosphere Substances 0.000 description 1
- QJGQUHMNIGDVPM-UHFFFAOYSA-N nitrogen group Chemical group [N] QJGQUHMNIGDVPM-UHFFFAOYSA-N 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
- 239000002736 nonionic surfactant Substances 0.000 description 1
- 239000003027 oil sand Substances 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 239000012466 permeate Substances 0.000 description 1
- JRKICGRDRMAZLK-UHFFFAOYSA-L peroxydisulfate Chemical compound [O-]S(=O)(=O)OOS([O-])(=O)=O JRKICGRDRMAZLK-UHFFFAOYSA-L 0.000 description 1
- 150000003014 phosphoric acid esters Chemical class 0.000 description 1
- 230000000704 physical effect Effects 0.000 description 1
- 229920002401 polyacrylamide Polymers 0.000 description 1
- 229920006254 polymer film Polymers 0.000 description 1
- 239000001103 potassium chloride Substances 0.000 description 1
- 235000011164 potassium chloride Nutrition 0.000 description 1
- 238000004321 preservation Methods 0.000 description 1
- 230000002265 prevention Effects 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 229940080818 propionamide Drugs 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 239000012966 redox initiator Substances 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 235000012239 silicon dioxide Nutrition 0.000 description 1
- 230000003068 static effect Effects 0.000 description 1
- 239000013589 supplement Substances 0.000 description 1
- 239000010936 titanium Substances 0.000 description 1
- 229910052719 titanium Inorganic materials 0.000 description 1
Images
Landscapes
- Detergent Compositions (AREA)
Abstract
The invention relates to an anti-wetting active blocking remover suitable for a low-permeability high-clay-content oil reservoir, which comprises the following raw material components in percentage by mass: 30-45 parts of acrylamide copolymer, 20-30 parts of fatty acid alkanolamide phosphate, 5-10 parts of petroleum sulfonate surfactant, 3-5 parts of limonene, 1.6-2.4 parts of fluorotitanate and 100-150 parts of water; the monomers of the acrylamide copolymer comprise acrylamide, sulfonate functionalized acrylamide, hydroxyl functionalized acrylamide and mercapto functionalized acrylamide. In the anti-wetting active blocking remover, the micromolecular surfactant system, the acrylamide copolymer and the fluotitanate are matched in a synergistic way, so that the anti-wetting active blocking remover has excellent oil-water interfacial tension, changes rock wettability, increases spontaneous imbibition effect performance and has excellent imbibition oil displacement effect. The blocking remover does not use cationic polymer, and the fatty acid alkanolamide phosphate is biodegradable and environment-friendly.
Description
Technical field:
the invention relates to the technical field of oil reservoir recovery efficiency improvement, in particular to an anti-wetting active blocking remover suitable for low-permeability high-clay-content oil reservoirs.
The background technology is as follows:
with the continuous exploration and development of conventional oil reservoirs, the conventional oil and gas reserves are greatly reduced, the energy requirements of China are difficult to meet, and the development of low-permeability compact oil reservoirs becomes an important succession resource for sustainable development of various oil fields. The low permeability compact oil reservoir has the basic characteristics of low pore and low permeability, the physical property of an oil layer is poor, injected water and stratum water are not compatible, the pore throat of the oil layer is tiny, the flow conductivity is poor, the injection-production relationship is imperfect or no injection-production relationship exists, the stratum energy supplement is difficult to effectively realize, and stratum blockage is easily caused.
The permeability of the low-permeability tight oil reservoir is low, fluid exchange is represented as imbibition to a large extent under the nano pore throat structural characteristics, capillary force of the reservoir plays a dominant role, and the low-permeability tight oil reservoir is a key index for influencing recovery ratio. Because the wettability of the reservoir is from weak parent oil to weak hydrophilcity, capillary force is resistance when water is injected, the wettability of the conventional surfactant solution can be changed, and the potential of improving the recovery ratio of low-permeability compact oil is provided, but the effect of adding the surfactant is absorbed by the rock surface and is difficult to play, and particularly for the stratum with higher clay content, the surfactant is quickly absorbed by clay and the like and loses effect. On the other hand, the rock contains a large amount of clay minerals, hydration and expansion are easy to occur after water injection, and the recovery efficiency is greatly reduced.
In order to obtain the blocking remover with the anti-clay hydration expansion function, fluorocarbon surfactant or cationic polymer is added, and the blocking remover is adsorbed on the clay surface to inhibit the hydration expansion of the clay by the characteristic that the clay surface has negative charges. However, neither the fluorocarbon surfactant nor the cationic polymer can degrade, adversely affecting the ecology of the formation water quality. Cationic polymers adsorb the surface of the rock minerals of the re-stratum, and long-term use can change the wettability of the stratum, thereby affecting the final recovery efficiency. And the general blocking remover contains anionic surfactant and cannot be applied together with cationic polymer. Creating construction difficulties.
CN111019621a discloses a green and environment-friendly biodegradable blocking remover, which comprises a bacillus boltzfeldt biosurfactant fermentation liquor and hydrophobic nano silicon dioxide. Avoiding pollution and pressure on water quality caused by using a large amount of surfactant. However, the Bacillus boltzfeldi is expensive, and the blocking removal effect is seriously reduced after a plurality of generations of reproduction, so that the Bacillus boltzfeldi has no industrial practicability.
The invention comprises the following steps:
the invention aims to provide an anti-wetting active plugging agent suitable for a low-permeability tight oil reservoir, so as to solve the problems in the prior art, enable the anti-wetting active plugging agent to have the effects of washing oil, reducing viscosity, inhibiting clay expansion and enhancing spontaneous imbibition, so as to permeate into micro-nano pore throats of the low-permeability tight oil reservoir, and improve the recovery ratio of the low-permeability tight oil reservoir.
In order to achieve the above object, the present invention provides the following solutions:
the invention provides an anti-wetting active blocking remover applicable to low-permeability high-clay-content oil reservoirs, which comprises the following raw material components in percentage by mass: 30-45 parts of acrylamide copolymer, 20-30 parts of fatty acid alkanolamide phosphate, 5-10 parts of petroleum sulfonate surfactant, 3-5 parts of limonene, 1.6-2.4 parts of fluorotitanate and 100-150 parts of water; monomers of the acrylamide copolymer include acrylamide, sulfonate functionalized acrylamide, hydroxyl functionalized acrylamide and mercapto functionalized acrylamide.
Further, in the monomer of the acrylamide copolymer, the mass ratio of the acrylamide to the sulfonate functionalized acrylamide to the hydroxyl functionalized acrylamide to the mercapto functionalized acrylamide is 50-70:20-30:20-30:12-18.
Still further, the sulfonate functionalized acrylamide is selected from the group consisting of 2-acrylamido-2-methylpropane sulfonate (sodium and/or potassium salt), and the hydroxy functionalized acrylamide is selected from at least one of N-methylolacrylamide, N- (hydroxymethyl) methacrylamide, N- (2-hydroxyethyl) acrylamide, N- (2-hydroxypropyl) acrylamide, N- [ tris (hydroxymethyl) methyl ] acrylamide; the mercapto-functional acrylamide is selected from mercaptoalkanoylacrylamides, such as mercaptoacetyl acrylamide, mercaptopropionylacrylamide.
The inventors have unexpectedly found that a propionamide copolymer obtained from the above four monomers, in combination with fluorotitanates, can effectively exert an effect of suppressing clay swelling in the blocking remover of the present invention. In order to suppress the hydration swelling of clay, a cationic polymer is generally used, and a polymer film is formed on the surface of clay by electrostatic adsorption of clay having negative charges on the surface, thereby suppressing the hydration swelling of clay. However, cationic polymers have several disadvantages for oilfield plugging removal agents, namely, they cannot be used with anionic surfactants, which are commonly contained in plugging removal agents; secondly, the cationic surfactant is adsorbed on the surface of stratum rock mineral substances, so that the wettability of the stratum can be changed after long-term use, and the final recovery ratio is affected; thirdly, the cationic polymer has an adverse effect on the formation water quality. The inventors have made the contrary that the use of acrylamide polymers with anionic monomers, in combination with high-valence metal ions, can provide excellent clay anti-swelling properties. The possible reason is that the high-valent metal cations act as complex crosslinks between the acrylamide copolymer and the clay surface; it is also possible that the hydroxyl groups and mercapto groups on the polymer have strong affinity to the clay surface, and after being injected into an oil well, the mercapto groups are attached to the clay surface, so that the osmotic hydration expansion of the clay is effectively inhibited. The hydration swelling of clay is divided into two types, one is surface hydration swelling and the other is osmotic swelling. The cationic polymer adsorbed on the clay surface can inhibit surface hydration expansion, and when the crystal layer spacing of the clay is large, the expansion is mainly osmotic expansion. Cationic polymers are not conducive to inhibiting osmotic swelling due to the repulsive force of the electric double layer. When the expansion force breaks down the electrostatic attraction, cations are diffused, and water molecules enter the clay crystal layer in a large amount to generate osmotic hydration. The blocking remover can effectively inhibit hydration expansion of clay under the combined action of the acrylamide copolymer and the fluotitanate.
The mercaptoalkanoyl acrylamide is obtained by reacting acrylamide with mercaptoalkyl acid under alkaline conditions. The mercaptoalkyl acid is at least one selected from mercaptoacetic acid, mercaptopropionic acid and mercaptobutyric acid. Specifically, the molar ratio of acrylamide to mercaptoalkyl acid is 1-1.2:1, and reacting for 3-5h at 30-40 ℃ under the condition of 1-2M NaOH to obtain the product of mercaptoalkyl acyl acrylamide.
Further, the acrylamide copolymer is obtained by a preparation method comprising the following steps: dissolving monomer acrylamide, sulfonate functionalized acrylamide, hydroxyl functionalized acrylamide and mercapto functionalized acrylamide in water, regulating the pH to 8-10, adding an initiator under inert atmosphere, heating to initiate polymerization reaction, washing, drying and crushing after the reaction is finished to obtain the acrylamide copolymer.
Further, in the preparation method of the acrylamide copolymer, the pH is regulated by sodium hydroxide and/or potassium hydroxide, the inert atmosphere is nitrogen and/or argon, the temperature is raised to 40-50 ℃, the initiator is a water-soluble initiator, such as a redox initiation system of persulfate and bisulfite, and the mass ratio of ammonium persulfate to sodium bisulfite is 1-2: 1-2. The addition amount of the initiator is 0.5-1wt% of the total mass of the monomers. The washing is with absolute ethanol and/or absolute acetone.
The fatty acid alkanolamide phosphate surfactant is selected from the group consisting of palmitic acid monoethanolamide phosphate, capric acid monoethanolamide phosphate, cocoate monoethanolamide phosphate, lauric acid monoethanolamide phosphate. The fatty acid alkanolamide phosphate has excellent wettability and corrosion inhibition performance, is well compatible with reservoir geological water, can be biodegraded, and is suitable for a plugging removing agent surfactant of a reservoir.
The petroleum fraction in the petroleum sulfonate surfactant is 200-300 ℃, preferably 240-260 ℃. Petroleum sulfonate surfactants are commonly used in oil displacement. The surfactant is compatible with fatty acid alkanolamide phosphate surfactant, so that the oil-water interfacial tension is reduced, the oil washing efficiency is improved, and the crude oil recovery ratio is improved. The catalyst is prepared by the steps of sulfonating the mixture with a sulfonating agent, and then neutralizing with alkali. The salt comprises sodium salt, potassium salt, barium salt, magnesium salt, calcium salt, etc.
The fluorotitanate is at least one selected from sodium fluorotitanate and potassium fluorotitanate. The titanium ions released by the fluorotitanate are selected to play a role in bridging and coupling between the clay surface and the acrylamide copolymer. Enhancing the function of the acrylamide copolymer for inhibiting the hydration expansion of clay.
The second purpose of the invention is to provide a preparation method of the anti-wetting active blocking remover suitable for the low-permeability high-clay-content oil reservoir, which comprises the following steps:
1) Mixing fatty acid alkanolamide phosphate, petroleum sulfonate surfactant, acrylamide copolymer and water according to the mass fraction ratio;
2) And dropwise adding limonene under stirring, continuing stirring until the mixture is clear and transparent, keeping the stability, adding fluotitanate, and uniformly mixing to obtain the anti-wetting active blocking remover.
When the blocking remover is used, the blocking remover is diluted to a certain concentration by water, for example, according to the following steps of 1: dilution was performed at a mass ratio of 100-200.
The invention further aims to provide application of the anti-wetting active blocking remover for the low-permeability high-clay-content oil reservoir in improving recovery efficiency of the low-permeability dense oil reservoir.
The invention carries out the well-stewed and the stratum energy is supplemented after the diluted anti-wetting active blocking remover solution is injected, thereby having the capability of converting the wettability of the rock surface from oil wet to water wet, triggering spontaneous imbibition displacement of reservoir oil to improve the recovery ratio of low-permeability compact oil reservoir, realizing the aim of blocking removal imbibition and energy increase integration, improving the single well yield and prolonging the exploitation life.
Further, the anti-wetting active blocking remover is diluted by water for 100-150 times and then injected into an oil well.
Compared with the background technology, the invention has the following beneficial effects:
1. the main components of the low-permeability high-clay-content oil reservoir anti-wetting active blocking remover disclosed by the invention are a micromolecular surfactant system formed by compounding a fatty acid alkanolamide phosphate nonionic surfactant and a petroleum sulfonate anionic surfactant, a polymer system of an acrylamide copolymer and fluotitanate, and the synergistic cooperation of the three components ensures that the blocking remover disclosed by the invention has excellent oil-water interfacial tension, can change the wettability of rock and can increase the spontaneous imbibition effect; the highly hydrophobic driving surfactant of the organic penetrant forms stable 'core-shell' nano micelle particles (< 50 nm), has extremely strong penetrating power and can penetrate into deeper pore throats; the nano micelle outer core highly hydrophilic coat (surfactant hydrophilic chain group) can reduce adsorption loss with reservoir rock when flowing in a weak-oil or weak-hydrophilic reservoir pore canal, and transport the blocking remover into a deeper pore canal. When the deep crude oil is encountered, the lipophilicity of the organic penetrant molecules and the hydrophobic end of the surfactant tend to interact with the crude oil, the core-shell structure is opened, the nano micelle releases the internal organic penetrant molecules, and the internal organic penetrant molecules enter the crude oil to interact with crude oil components such as asphaltene and colloid, so that the crude oil is disentangled and unassociated, the crude oil is promoted to be stripped and flow out, and under the comprehensive mechanism, the anti-wettability plugging agent has a good imbibition oil displacement effect.
2. The anti-wetting active blocking remover does not use cationic polymer, and the added reagent is environment-friendly. Fatty acid alkanolamide phosphate esters are biodegradable. The acrylamide copolymer is easy to discharge from the stratum along with water injection, and can not adversely affect the geology and water quality of the oil reservoir after long-term use.
3. The anti-wetting active blocking remover is very suitable for low-permeability and high-viscosity oil reservoir geology, and can effectively improve recovery ratio.
Drawings
FIG. 1 is a photograph of a blocking remover prepared in example 1 of the present invention.
FIG. 2 is a photograph of an oilfield in-situ construction using the deblocking agent prepared in example 1 of the present invention.
The specific embodiment is as follows:
the invention will be further illustrated with reference to specific examples:
petroleum sulfonate PS-NB is purchased from Hubei Korea chemical Co., ltd, and the petroleum fraction is 240-260 ℃.
Unless otherwise specified, "parts" in the embodiments of the present invention are parts by mass, and "%" is a mass percentage.
Preparation example 1
Dissolving acrylamide in a 1M NaOH solution, slowly adding thioglycollic acid at 30 ℃, wherein the molar ratio of the acrylamide to the thioglycollic acid is 1.1:1, and carrying out heat preservation reaction for 3 hours under stirring to obtain the mercaptoacetyl acrylamide.
Preparation example 2
50 parts of acrylamide, 30 parts of 2-acrylamide-2-methylpropanesulfonic acid sodium salt, 30 parts of N- (hydroxymethyl) methacrylamide and 12 parts of mercaptoacetyl acrylamide are dissolved in 500 parts of water, the pH is regulated to 8.5 by using a 5% NaOH solution, nitrogen is introduced to remove air, the temperature is raised to 40 ℃ under the protection of nitrogen atmosphere, an aqueous solution containing 0.61 part of an initiator (a mixture of ammonium persulfate and sodium bisulfite according to the mass ratio of 1:1) is slowly added, the reaction is kept for 3 hours, after the reaction is finished, the product is washed for 3 times by absolute ethanol, dried in vacuum at 80 ℃ under 0.1MPa, crushed and sieved by a 100-mesh sieve, and the acrylamide quadripolymer (hereinafter referred to as acrylamide copolymer 1) is obtained.
As a result of the test, the intrinsic viscosity of the acrylamide copolymer 1 obtained in preparation example 2 was 852mL/g.
Preparation example 3
The other conditions were the same as in preparation example 2 except that the monomers were 70 parts of acrylamide, 20 parts of 2-acrylamido-2-methylpropanesulfonic acid sodium salt, 30 parts of N-methylolacrylamide, 12 parts of mercaptoacetylacrylamide. The copolymer obtained was referred to as acrylamide copolymer 2. As a result of the test, the acrylamide copolymer 2 obtained in preparation example 3 had an intrinsic viscosity of 864mL/g.
Comparative example preparation example 1
The other conditions were the same as in preparation example 2 except that mercaptoacetylacrylamide was not added. The copolymer obtained is referred to as acrylamide copolymer a. The acrylamide copolymer a prepared in comparative preparation 1 was tested to have an intrinsic viscosity of 871mL/g.
Comparative preparation example 2
The other conditions were the same as in preparation example 2 except that 2-acrylamido-2-methylpropanesulfonic acid sodium salt was not added. The copolymer obtained is referred to as acrylamide copolymer b. The acrylamide copolymer b prepared in comparative preparation 2 was tested to have an intrinsic viscosity of 864mL/g.
Comparative preparation example 3
The other conditions were the same as in preparation example 2 except that N- (hydroxymethyl) methacrylamide was not added. The copolymer obtained is referred to as acrylamide copolymer c. The acrylamide copolymer c prepared in comparative preparation 3 was tested to have an intrinsic viscosity of 859mL/g.
Example 1:
weighing 30 parts of the acrylamide copolymer 1 prepared in preparation example 2, 30 parts of lauric acid monoethanolamide phosphate and 5 parts of petroleum sulfonate surfactant, putting into 100 parts of water, and stirring and mixing uniformly; 3 parts of limonene is added dropwise under stirring, stirring is continued until the mixture is clear and transparent, stability is maintained, and 1.6 parts of sodium fluotitanate is added, so that the anti-wetting active blocking remover 1 is prepared.
FIG. 1 is a photograph of an anti-wetting active blocking remover 1 prepared in example 1 as a tan viscous liquid.
Example 2
45 parts of acrylamide copolymer 1 prepared in preparation example 2, 20 parts of lauric acid monoethanolamide phosphate and 10 parts of petroleum sulfonate surfactant are weighed, put into 120 parts of water, and stirred and mixed uniformly; 5 parts of limonene is added dropwise under stirring, stirring is continued until the mixture is clear and transparent, stability is maintained, and 2.4 parts of sodium fluotitanate is added, so that the anti-wetting active blocking remover 2 is prepared.
Comparative example 1
Other conditions and operations were the same as in example 1 except that acrylamide copolymer 1 was replaced with an equal mass of acrylamide copolymer a obtained in comparative preparation example 1.
Comparative example 2
Other conditions and operations were the same as in example 1 except that acrylamide copolymer 1 was replaced with an equal mass of acrylamide copolymer b produced in comparative preparation 2.
Comparative example 3
Other conditions and operations were the same as in example 1 except that acrylamide copolymer 1 was replaced with an equal mass of acrylamide copolymer c obtained in comparative preparation 3.
Comparative example 4
Other conditions and operations were the same as in example 1 except that sodium fluorotitanate was not added.
Performance test I:
the anti-wetting active blocking remover 0.8g and the potassium chloride 0.5g obtained in the above examples and comparative examples were uniformly mixed with 98.7g of water to prepare an anti-wetting active blocking remover solution with a concentration of 0.8wt%, and the following performance tests were performed:
(1) Anti-swelling property
The hypotonic dense oil reservoir rock mineral contains a large amount of clay mineral, and the hydration expansion of clay directly influences the permeability of stratum. The anti-swelling is an important measure in the production and development process. Bentonite is adopted to test the anti-swelling rate of the anti-wetting active blocking remover solution.
Referring to SY/T5971-1994, a shale dilatometer was used to test the expansion resistance of the anti-wetting active blocking remover of the invention.
2g of bentonite is taken, placed in a shale swelling instrument, placed in 300mL of different solutions, placed for 24 hours, the swelling height of the bentonite in the different solutions is tested, and the swelling prevention rate is calculated according to the following formula:
wherein B is the anti-swelling rate,%; h 0 The expansion height of bentonite in kerosene is mm; h 1 The expansion height of bentonite in 0.5% of blocking remover solution is mm; h 2 Is the expansion height of bentonite in water, mm.
(2) Wash oil performance
When the bottom pressure is lower than the saturation pressure in the production process of the low permeability oil well, crude oil is degassed, organic asphaltene deposition occurs, so that the flow resistance of the crude oil is increased, the relative permeability is reduced, and the productivity is reduced. The plugging removing agent has better penetrating and dispersing effects after entering the stratum, and polar molecules of the plugging removing agent interact with asphaltene and colloid polar substances in crude oil, so that the viscosity of the crude oil can be reduced, and the stripping and outflow of the crude oil can be promoted.
The wash oil rate was tested as follows: and (3) fully mixing crude oil and quartz sand according to the mass ratio of 1:6, drying in a 60 ℃ oven until the weight is constant, taking 5.0g of dried oil sand, placing in a 100mL test tube, adding 40mL of 0.8% blocking remover solution, fully mixing, placing in a 60 ℃ incubator, standing for 48h, and shaking the test tube once every 12 h. After the standing is finished, sucking out the oil and the solution washed out of the test tube, dipping out the crude oil adhered to the bottle wall by using a cotton swab, drying the residual quartz sand to constant weight at 60 ℃, weighing the mass of the quartz sand, and calculating the oil washing rate according to the following formula:
wherein A is the oil washing rate,%; m is m 1 G is the total mass of the test tube and quartz sand before oil washing; m is m 2 G is the total mass of the test tube and quartz sand after oil washing; m is m 3 G, the total mass of the test tube and quartz sand after cleaning;
(3) Interfacial tension Property
The interfacial tension of a 0.8% anti-wetting active blocking remover solution was tested with reference to SY/T5370-1999.
(4) Rock dewetting Property
The natural rock core (phi 2.5 multiplied by 2.5cm, wetting angle 99.3 DEG) is respectively put into a grinding bottle filled with 0.5% anti-wetting active blocking remover solution of the examples and the comparative examples, the blocking remover solution is immersed into the rock core, the grinding bottle is placed into a constant temperature box at 25 ℃, the rock core is taken out and dried after being immersed for 24 hours, and the wetting angle theta of the surface of the rock core is measured. After 24h of soaking, the surface wetting angle of the test core is changed from neutral wetting to water wetting.
Self-seepage and absorption performance of rock for use in a step of bathing
Drying and weighing the rock core (phi 2.5 multiplied by 2.5 cm), weighing wet weight by using water for vacuumizing saturated experiments, and calculating the pore volume; oil flooding is carried out under the condition of the reservoir temperature, so that the rock core is saturated with experimental oil, the crude oil is aged for 24 hours by standing, and the oil saturation is calculated; vacuumizing the experimental water and 0.8% anti-wetting active blocking remover solution for 3 hours to eliminate the adverse effect of dissolved gas in the solution on core imbibition and oil displacement; soaking the core in a imbibition bottle filled with 0.8% anti-wetting active blocking remover solution, and performing imbibition experiment; recording the change of imbibition and oil discharge in different time periods, and calculating the imbibition recovery ratio according to the following formula:
wherein:
η—recovery rate of permeation,%;
V o the volume of the oil discharged during static imbibition is cm 3 ；
V w -volume of core saturated oil, cm 3 。
TABLE 1 blocking remover Performance test results
Performance test II:
on-site effect test of the plugging removing agent prepared in the embodiment 1 of the invention on the Tibetan shellfish 301 block B6157 well: the clay mineral of the reservoir of the shellfish 301 block has the main components of montmorillonite (18.7%) which is a strong water sensitivity mineral, illite (44.9%) which is a quick sensitivity mineral, and kaolinite (31.0%), and the reservoir has strong water sensitivity. The special hypotonic and hypotonic are the main. Table 2 is the natural core sensitivity experimental data for the zone 301 of shellfish. Intermittent pumping production is carried out before the measure of the B6157 well, the blocking removing and imbibition agent is adopted for injecting into an oil layer, and well closing reaction is carried out for 24 hours; open well production, under the condition that the oil well resumes normal production, daily liquid production amount is 3.29m 3 Up to 12m 3 Daily oil production is increased from 0.67t to 1.55t, and the yield is increased by more than 2 times. The results are shown in Table 3.
TABLE 2 data of sensitive experiments on natural cores in the shellfish 301 region
Table 3 oilfield recovery receipts
Claims (10)
1. The anti-wetting active blocking remover suitable for the low-permeability high-clay-content oil reservoir is characterized by comprising the following raw material components in parts by mass: 30-45 parts of acrylamide copolymer, 20-30 parts of fatty acid alkanolamide phosphate, 5-10 parts of petroleum sulfonate surfactant, 3-5 parts of limonene, 1.6-2.4 parts of fluorotitanate and 100-150 parts of water; the acrylamide copolymer comprises the following monomers in percentage by mass: 20-30:20-30:12-18, sulfonate functionalized acrylamides, hydroxy functionalized acrylamides, and mercapto functionalized acrylamides;
the mercapto-functional acrylamide is mercaptoalkanoyl acrylamide; the mercaptoalkanoyl acrylamide is selected from mercaptoacetyl acrylamide and mercaptopropionyl acrylamide;
the sulfonate functionalized acrylamide is selected from 2-acrylamide-2-methylpropane sulfonate, and the hydroxyl functionalized acrylamide is at least one selected from N-methylol acrylamide, N- (hydroxymethyl) methacrylamide, N- (2-hydroxyethyl) acrylamide, N- (2-hydroxypropyl) acrylamide and N- [ tri (hydroxymethyl) methyl ] acrylamide.
2. The oil reservoir anti-wetting active blocking remover according to claim 1, wherein the 2-acrylamide-2-methylpropanesulfonate is sodium salt and/or potassium salt thereof.
3. The oil reservoir anti-wetting active blocking remover according to claim 1, wherein the mercaptoalkanoyl acrylamide is obtained by reacting acrylamide with mercaptoalkyl acid under alkaline conditions; the mercaptoalkyl acid is at least one selected from mercaptoacetic acid and mercaptopropionic acid.
4. The oil reservoir anti-wetting active blocking remover according to claim 1, wherein the acrylamide copolymer is obtained by a preparation method comprising the following steps: dissolving monomer acrylamide, sulfonate functionalized acrylamide, hydroxyl functionalized acrylamide and mercapto functionalized acrylamide in water, regulating the pH to 8-10, adding an initiator under inert atmosphere, heating to initiate polymerization reaction, washing, drying and crushing after the reaction is finished to obtain the acrylamide copolymer.
5. The reservoir anti-wetting active plugging remover according to claim 1, wherein the fatty acid alkanolamide phosphate is at least one selected from the group consisting of palmitic acid monoethanolamide phosphate, capric acid monoethanolamide phosphate, coco acid monoethanolamide phosphate, and cinnamic acid monoethanolamide phosphate.
6. The oil reservoir anti-wetting active deblocking agent of claim 1, wherein the petroleum fraction in the petroleum sulfonate surfactant is 200-300 ℃.
7. The oil reservoir anti-wetting active deblocking agent of claim 6, wherein the petroleum fraction in the petroleum sulfonate surfactant is 240-260 ℃.
8. The oil reservoir anti-wetting active blocking remover according to claim 1, wherein the fluotitanate is at least one selected from sodium fluotitanate and potassium fluotitanate.
9. The method for preparing the anti-wetting active blocking remover for the low-permeability high-clay-content oil reservoir according to any one of claims 1 to 8, which is characterized by comprising the following steps:
1) Mixing fatty acid alkanolamide phosphate, petroleum sulfonate surfactant, acrylamide copolymer and water according to the mass part ratio;
2) And dropwise adding limonene under stirring, continuing stirring until the mixture is clear and transparent, keeping the stability, adding fluotitanate, and uniformly mixing to obtain the anti-wetting active blocking remover.
10. Use of an anti-wetting active plugging agent according to any one of claims 1-8 for enhanced recovery from low permeability dense reservoirs.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202211467802.4A CN115746810B (en) | 2022-11-22 | 2022-11-22 | Anti-wetting active blocking remover applicable to low-permeability high-clay-content oil reservoir |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202211467802.4A CN115746810B (en) | 2022-11-22 | 2022-11-22 | Anti-wetting active blocking remover applicable to low-permeability high-clay-content oil reservoir |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN115746810A CN115746810A (en) | 2023-03-07 |
| CN115746810B true CN115746810B (en) | 2023-06-13 |
Family
ID=85336847
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202211467802.4A Active CN115746810B (en) | 2022-11-22 | 2022-11-22 | Anti-wetting active blocking remover applicable to low-permeability high-clay-content oil reservoir |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN115746810B (en) |
Families Citing this family (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN117678602B (en) * | 2024-02-02 | 2024-04-16 | 山东奥坤作物科学股份有限公司 | Weeding composition and preparation method thereof |
Citations (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN112251208A (en) * | 2020-10-26 | 2021-01-22 | 德仕能源科技集团股份有限公司 | Oil displacement surfactant for high-temperature high-salt oil reservoir and preparation method and application thereof |
Family Cites Families (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US7268100B2 (en) * | 2004-11-29 | 2007-09-11 | Clearwater International, Llc | Shale inhibition additive for oil/gas down hole fluids and methods for making and using same |
| CN104231164B (en) * | 2013-06-20 | 2016-05-25 | 中国石油化工股份有限公司 | A kind of acrylamide based copolymer and its preparation method and application |
| CN106497538A (en) * | 2016-10-25 | 2017-03-15 | 长江大学 | Drag reduction, the row of helping and clay stabilization " three-in-one " slippery water concentrate system without oil phase |
| CN109852358A (en) * | 2019-03-29 | 2019-06-07 | 天津市擎华能源技术有限责任公司 | A kind of de-plugging agent |
-
2022
- 2022-11-22 CN CN202211467802.4A patent/CN115746810B/en active Active
Patent Citations (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN112251208A (en) * | 2020-10-26 | 2021-01-22 | 德仕能源科技集团股份有限公司 | Oil displacement surfactant for high-temperature high-salt oil reservoir and preparation method and application thereof |
Also Published As
| Publication number | Publication date |
|---|---|
| CN115746810A (en) | 2023-03-07 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CA2920880C (en) | Aqueous downhole fluids having charged nano-particles and polymers | |
| US20040209780A1 (en) | Methods of treating subterranean formations using hydrophobically modified polymers and compositions of the same | |
| US20080139411A1 (en) | Methods of treating subterranean formations using hydrophobically modified polymers and compositions of the same | |
| AU2015374328B2 (en) | Emulsions containing alkyl ether sulfates and uses thereof | |
| CN102174314B (en) | Organic silicon fluid loss additive and preparation method thereof | |
| CN115746810B (en) | Anti-wetting active blocking remover applicable to low-permeability high-clay-content oil reservoir | |
| Zhou et al. | Preparation and performance evaluation of an active nanofluid for enhanced oil recovery in ultra-low permeability reservoirs | |
| US11542425B1 (en) | Leak-proof lost-circulation control water-based drilling fluid composition and preparation method and use thereof | |
| WO2015074588A1 (en) | Zirconium dispersed-particle gel combination flooding system and preparation method thereof | |
| CN109439307A (en) | A kind of foam system and preparation method thereof that oil gas field is strengthened with graphene armor | |
| CN106749891B (en) | It is applicable amphoteric ion copolymer of drilling fluid filtrate reducing and its preparation method and application and drilling fluid and its application | |
| CN112358862A (en) | Oil displacement and viscosity reduction fracturing fluid suitable for low-fluidity compact oil reservoir | |
| CN105385431A (en) | Nano emulsion injection stimulation agent for oil field water injection, preparation method thereof and oil field water injection system | |
| CA2782434C (en) | Thermally stable, nonionic foaming agent for foam fracturing fluids | |
| CN108485627A (en) | A kind of preparation of water filling with oil cleaning clay expansion-resisting agent | |
| CN106084142A (en) | It is applicable to nucleocapsid shape polymer of oil field produced water and preparation method thereof | |
| CN106749836B (en) | Copolymer suitable for filtrate reducing with temperature resistance anticalcium ability and its preparation method and application and drilling fluid and its application | |
| CN117003940A (en) | Double-effect inhibitor suitable for well wall stabilization of natural gas hydrate reservoir, and preparation method and application thereof | |
| CA3144194A1 (en) | Friction reducers for high tds brines | |
| CN111978937B (en) | Temperature-resistant deformable polymer fluid loss additive for drilling fluid and preparation method thereof | |
| CN106318348B (en) | Thick oil pollution resistant drilling fluid | |
| CN117412999A (en) | Water-soluble associative amphoteric polymers as rheology modifiers for subterranean treatments | |
| CN113861956A (en) | Nano drag reducer for oil well and preparation method thereof | |
| CN111961451A (en) | Oil-gas well slow-release foaming agent and preparation method thereof | |
| CN113201100B (en) | In-situ demulsification functional associated polymer oil-displacing agent and preparation method thereof |
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 |