WO2014189584A1 - Precipitated particles and wellbore fluids and methods relating thereto - Google Patents
Precipitated particles and wellbore fluids and methods relating thereto Download PDFInfo
- Publication number
- WO2014189584A1 WO2014189584A1 PCT/US2014/019818 US2014019818W WO2014189584A1 WO 2014189584 A1 WO2014189584 A1 WO 2014189584A1 US 2014019818 W US2014019818 W US 2014019818W WO 2014189584 A1 WO2014189584 A1 WO 2014189584A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- wellbore
- fluid
- precipitated particles
- particles
- precipitated
- Prior art date
Links
- 239000002245 particle Substances 0.000 title claims abstract description 336
- 239000012530 fluid Substances 0.000 title claims abstract description 280
- 238000000034 method Methods 0.000 title description 30
- 238000005553 drilling Methods 0.000 claims abstract description 81
- 241000950638 Symphysodon discus Species 0.000 claims abstract description 30
- HOQADATXFBOEGG-UHFFFAOYSA-N isofenphos Chemical compound CCOP(=S)(NC(C)C)OC1=CC=CC=C1C(=O)OC(C)C HOQADATXFBOEGG-UHFFFAOYSA-N 0.000 claims abstract description 30
- 238000004891 communication Methods 0.000 claims abstract description 10
- 230000005484 gravity Effects 0.000 claims description 38
- 238000009826 distribution Methods 0.000 claims description 36
- 238000012545 processing Methods 0.000 claims description 14
- 230000008859 change Effects 0.000 claims description 10
- 229910052500 inorganic mineral Inorganic materials 0.000 abstract description 9
- 239000011707 mineral Substances 0.000 abstract description 9
- -1 titanates Chemical class 0.000 description 66
- 239000000203 mixture Substances 0.000 description 41
- 239000003795 chemical substances by application Substances 0.000 description 37
- 229920000642 polymer Polymers 0.000 description 27
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 20
- 239000000654 additive Substances 0.000 description 20
- 230000015572 biosynthetic process Effects 0.000 description 20
- 238000000576 coating method Methods 0.000 description 20
- 239000003607 modifier Substances 0.000 description 19
- 238000001556 precipitation Methods 0.000 description 19
- 238000005755 formation reaction Methods 0.000 description 18
- 239000000839 emulsion Substances 0.000 description 17
- 239000004094 surface-active agent Substances 0.000 description 15
- 239000011248 coating agent Substances 0.000 description 14
- 239000011133 lead Substances 0.000 description 14
- 150000003839 salts Chemical class 0.000 description 14
- XLOMVQKBTHCTTD-UHFFFAOYSA-N Zinc monoxide Chemical compound [Zn]=O XLOMVQKBTHCTTD-UHFFFAOYSA-N 0.000 description 13
- 230000008901 benefit Effects 0.000 description 13
- 239000011575 calcium Substances 0.000 description 13
- VTYYLEPIZMXCLO-UHFFFAOYSA-L Calcium carbonate Chemical compound [Ca+2].[O-]C([O-])=O VTYYLEPIZMXCLO-UHFFFAOYSA-L 0.000 description 12
- QPLDLSVMHZLSFG-UHFFFAOYSA-N Copper oxide Chemical compound [Cu]=O QPLDLSVMHZLSFG-UHFFFAOYSA-N 0.000 description 12
- 239000002585 base Substances 0.000 description 12
- 239000010949 copper Substances 0.000 description 12
- 229910052742 iron Inorganic materials 0.000 description 12
- MHAJPDPJQMAIIY-UHFFFAOYSA-N Hydrogen peroxide Chemical compound OO MHAJPDPJQMAIIY-UHFFFAOYSA-N 0.000 description 11
- TZCXTZWJZNENPQ-UHFFFAOYSA-L barium sulfate Chemical compound [Ba+2].[O-]S([O-])(=O)=O TZCXTZWJZNENPQ-UHFFFAOYSA-L 0.000 description 11
- 229910000019 calcium carbonate Inorganic materials 0.000 description 11
- 229910000016 manganese(II) carbonate Inorganic materials 0.000 description 11
- VASIZKWUTCETSD-UHFFFAOYSA-N manganese(II) oxide Inorganic materials [Mn]=O VASIZKWUTCETSD-UHFFFAOYSA-N 0.000 description 11
- 230000015556 catabolic process Effects 0.000 description 10
- 238000006731 degradation reaction Methods 0.000 description 10
- AMWRITDGCCNYAT-UHFFFAOYSA-L manganese oxide Inorganic materials [Mn].O[Mn]=O.O[Mn]=O AMWRITDGCCNYAT-UHFFFAOYSA-L 0.000 description 10
- 238000004519 manufacturing process Methods 0.000 description 10
- 229910052791 calcium Inorganic materials 0.000 description 9
- 239000011777 magnesium Substances 0.000 description 9
- NUJOXMJBOLGQSY-UHFFFAOYSA-N manganese dioxide Inorganic materials O=[Mn]=O NUJOXMJBOLGQSY-UHFFFAOYSA-N 0.000 description 9
- 229910052845 zircon Inorganic materials 0.000 description 9
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 8
- CPLXHLVBOLITMK-UHFFFAOYSA-N Magnesium oxide Chemical compound [Mg]=O CPLXHLVBOLITMK-UHFFFAOYSA-N 0.000 description 8
- XOLBLPGZBRYERU-UHFFFAOYSA-N SnO2 Inorganic materials O=[Sn]=O XOLBLPGZBRYERU-UHFFFAOYSA-N 0.000 description 8
- AYJRCSIUFZENHW-UHFFFAOYSA-L barium carbonate Inorganic materials [Ba+2].[O-]C([O-])=O AYJRCSIUFZENHW-UHFFFAOYSA-L 0.000 description 8
- 239000004568 cement Substances 0.000 description 8
- 239000004088 foaming agent Substances 0.000 description 8
- JEIPFZHSYJVQDO-UHFFFAOYSA-N iron(III) oxide Inorganic materials O=[Fe]O[Fe]=O JEIPFZHSYJVQDO-UHFFFAOYSA-N 0.000 description 8
- 229910052749 magnesium Inorganic materials 0.000 description 8
- 239000011572 manganese Substances 0.000 description 8
- 235000010755 mineral Nutrition 0.000 description 8
- 238000002156 mixing Methods 0.000 description 8
- 125000006850 spacer group Chemical group 0.000 description 8
- 229910000010 zinc carbonate Inorganic materials 0.000 description 8
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 7
- PXHVJJICTQNCMI-UHFFFAOYSA-N Nickel Chemical compound [Ni] PXHVJJICTQNCMI-UHFFFAOYSA-N 0.000 description 7
- WMWLMWRWZQELOS-UHFFFAOYSA-N bismuth(III) oxide Inorganic materials O=[Bi]O[Bi]=O WMWLMWRWZQELOS-UHFFFAOYSA-N 0.000 description 7
- OMZSGWSJDCOLKM-UHFFFAOYSA-N copper(II) sulfide Chemical compound [S-2].[Cu+2] OMZSGWSJDCOLKM-UHFFFAOYSA-N 0.000 description 7
- 229910052955 covellite Inorganic materials 0.000 description 7
- 238000000227 grinding Methods 0.000 description 7
- 239000011656 manganese carbonate Substances 0.000 description 7
- 235000006748 manganese carbonate Nutrition 0.000 description 7
- 229940093474 manganese carbonate Drugs 0.000 description 7
- XMWCXZJXESXBBY-UHFFFAOYSA-L manganese(ii) carbonate Chemical compound [Mn+2].[O-]C([O-])=O XMWCXZJXESXBBY-UHFFFAOYSA-L 0.000 description 7
- GWEVSGVZZGPLCZ-UHFFFAOYSA-N titanium dioxide Inorganic materials O=[Ti]=O GWEVSGVZZGPLCZ-UHFFFAOYSA-N 0.000 description 7
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 description 6
- LYCAIKOWRPUZTN-UHFFFAOYSA-N Ethylene glycol Chemical compound OCCO LYCAIKOWRPUZTN-UHFFFAOYSA-N 0.000 description 6
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical compound OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 description 6
- DNIAPMSPPWPWGF-UHFFFAOYSA-N Propylene glycol Chemical compound CC(O)CO DNIAPMSPPWPWGF-UHFFFAOYSA-N 0.000 description 6
- GNTDGMZSJNCJKK-UHFFFAOYSA-N Vanadium(V) oxide Inorganic materials O=[V](=O)O[V](=O)=O GNTDGMZSJNCJKK-UHFFFAOYSA-N 0.000 description 6
- 239000007789 gas Substances 0.000 description 6
- 239000007788 liquid Substances 0.000 description 6
- 230000014759 maintenance of location Effects 0.000 description 6
- GEYXPJBPASPPLI-UHFFFAOYSA-N manganese(III) oxide Inorganic materials O=[Mn]O[Mn]=O GEYXPJBPASPPLI-UHFFFAOYSA-N 0.000 description 6
- CWQXQMHSOZUFJS-UHFFFAOYSA-N molybdenum disulfide Chemical compound S=[Mo]=S CWQXQMHSOZUFJS-UHFFFAOYSA-N 0.000 description 6
- JKQOBWVOAYFWKG-UHFFFAOYSA-N molybdenum trioxide Inorganic materials O=[Mo](=O)=O JKQOBWVOAYFWKG-UHFFFAOYSA-N 0.000 description 6
- QHGNHLZPVBIIPX-UHFFFAOYSA-N tin(II) oxide Inorganic materials [Sn]=O QHGNHLZPVBIIPX-UHFFFAOYSA-N 0.000 description 6
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 6
- 239000011787 zinc oxide Substances 0.000 description 6
- 229910000014 Bismuth subcarbonate Inorganic materials 0.000 description 5
- 229910000003 Lead carbonate Inorganic materials 0.000 description 5
- WAEMQWOKJMHJLA-UHFFFAOYSA-N Manganese(2+) Chemical class [Mn+2] WAEMQWOKJMHJLA-UHFFFAOYSA-N 0.000 description 5
- 238000005299 abrasion Methods 0.000 description 5
- QVQLCTNNEUAWMS-UHFFFAOYSA-N barium oxide Inorganic materials [Ba]=O QVQLCTNNEUAWMS-UHFFFAOYSA-N 0.000 description 5
- 239000010428 baryte Substances 0.000 description 5
- 229910052601 baryte Inorganic materials 0.000 description 5
- 239000000292 calcium oxide Substances 0.000 description 5
- ODINCKMPIJJUCX-UHFFFAOYSA-N calcium oxide Inorganic materials [Ca]=O ODINCKMPIJJUCX-UHFFFAOYSA-N 0.000 description 5
- 150000001875 compounds Chemical class 0.000 description 5
- BERDEBHAJNAUOM-UHFFFAOYSA-N copper(I) oxide Inorganic materials [Cu]O[Cu] BERDEBHAJNAUOM-UHFFFAOYSA-N 0.000 description 5
- 229910052593 corundum Inorganic materials 0.000 description 5
- 229910052840 fayalite Inorganic materials 0.000 description 5
- 239000006260 foam Substances 0.000 description 5
- 229910001691 hercynite Inorganic materials 0.000 description 5
- 230000001965 increasing effect Effects 0.000 description 5
- 229910000015 iron(II) carbonate Inorganic materials 0.000 description 5
- SZVJSHCCFOBDDC-UHFFFAOYSA-N iron(II,III) oxide Inorganic materials O=[Fe]O[Fe]O[Fe]=O SZVJSHCCFOBDDC-UHFFFAOYSA-N 0.000 description 5
- 239000000395 magnesium oxide Substances 0.000 description 5
- 239000000693 micelle Substances 0.000 description 5
- 229910052953 millerite Inorganic materials 0.000 description 5
- 229910052982 molybdenum disulfide Inorganic materials 0.000 description 5
- 239000003921 oil Substances 0.000 description 5
- NIFIFKQPDTWWGU-UHFFFAOYSA-N pyrite Chemical compound [Fe+2].[S-][S-] NIFIFKQPDTWWGU-UHFFFAOYSA-N 0.000 description 5
- 229910052712 strontium Inorganic materials 0.000 description 5
- IATRAKWUXMZMIY-UHFFFAOYSA-N strontium oxide Inorganic materials [O-2].[Sr+2] IATRAKWUXMZMIY-UHFFFAOYSA-N 0.000 description 5
- KFZMGEQAYNKOFK-UHFFFAOYSA-N Isopropanol Chemical compound CC(C)O KFZMGEQAYNKOFK-UHFFFAOYSA-N 0.000 description 4
- LRHPLDYGYMQRHN-UHFFFAOYSA-N N-Butanol Chemical compound CCCCO LRHPLDYGYMQRHN-UHFFFAOYSA-N 0.000 description 4
- 239000004698 Polyethylene Substances 0.000 description 4
- 229920002873 Polyethylenimine Polymers 0.000 description 4
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 4
- DKGAVHZHDRPRBM-UHFFFAOYSA-N Tert-Butanol Chemical compound CC(C)(C)O DKGAVHZHDRPRBM-UHFFFAOYSA-N 0.000 description 4
- 229910001308 Zinc ferrite Inorganic materials 0.000 description 4
- MCMNRKCIXSYSNV-UHFFFAOYSA-N ZrO2 Inorganic materials O=[Zr]=O MCMNRKCIXSYSNV-UHFFFAOYSA-N 0.000 description 4
- 239000002253 acid Substances 0.000 description 4
- 230000000996 additive effect Effects 0.000 description 4
- PNEYBMLMFCGWSK-UHFFFAOYSA-N aluminium oxide Inorganic materials [O-2].[O-2].[O-2].[Al+3].[Al+3] PNEYBMLMFCGWSK-UHFFFAOYSA-N 0.000 description 4
- LTPBRCUWZOMYOC-UHFFFAOYSA-N beryllium oxide Inorganic materials O=[Be] LTPBRCUWZOMYOC-UHFFFAOYSA-N 0.000 description 4
- 229910052797 bismuth Inorganic materials 0.000 description 4
- JCXGWMGPZLAOME-UHFFFAOYSA-N bismuth atom Chemical compound [Bi] JCXGWMGPZLAOME-UHFFFAOYSA-N 0.000 description 4
- 229910052948 bornite Inorganic materials 0.000 description 4
- BTANRVKWQNVYAZ-UHFFFAOYSA-N butan-2-ol Chemical compound CCC(C)O BTANRVKWQNVYAZ-UHFFFAOYSA-N 0.000 description 4
- 229910052980 cadmium sulfide Inorganic materials 0.000 description 4
- NNLOHLDVJGPUFR-UHFFFAOYSA-L calcium;3,4,5,6-tetrahydroxy-2-oxohexanoate Chemical compound [Ca+2].OCC(O)C(O)C(O)C(=O)C([O-])=O.OCC(O)C(O)C(O)C(=O)C([O-])=O NNLOHLDVJGPUFR-UHFFFAOYSA-L 0.000 description 4
- 239000001569 carbon dioxide Substances 0.000 description 4
- 229910002092 carbon dioxide Inorganic materials 0.000 description 4
- YCIMNLLNPGFGHC-UHFFFAOYSA-N catechol Chemical compound OC1=CC=CC=C1O YCIMNLLNPGFGHC-UHFFFAOYSA-N 0.000 description 4
- 229910052951 chalcopyrite Inorganic materials 0.000 description 4
- DVRDHUBQLOKMHZ-UHFFFAOYSA-N chalcopyrite Chemical compound [S-2].[S-2].[Fe+2].[Cu+2] DVRDHUBQLOKMHZ-UHFFFAOYSA-N 0.000 description 4
- 230000007423 decrease Effects 0.000 description 4
- 150000002148 esters Chemical class 0.000 description 4
- 229910052965 gersdorffite Inorganic materials 0.000 description 4
- 229910052909 inorganic silicate Inorganic materials 0.000 description 4
- 229910021519 iron(III) oxide-hydroxide Inorganic materials 0.000 description 4
- ZXEKIIBDNHEJCQ-UHFFFAOYSA-N isobutanol Chemical compound CC(C)CO ZXEKIIBDNHEJCQ-UHFFFAOYSA-N 0.000 description 4
- 229910000471 manganese heptoxide Inorganic materials 0.000 description 4
- 229910052960 marcasite Inorganic materials 0.000 description 4
- 239000000463 material Substances 0.000 description 4
- 229910052961 molybdenite Inorganic materials 0.000 description 4
- QXYJCZRRLLQGCR-UHFFFAOYSA-N molybdenum(IV) oxide Inorganic materials O=[Mo]=O QXYJCZRRLLQGCR-UHFFFAOYSA-N 0.000 description 4
- 229920001467 poly(styrenesulfonates) Polymers 0.000 description 4
- 229960002796 polystyrene sulfonate Drugs 0.000 description 4
- 239000011970 polystyrene sulfonate Substances 0.000 description 4
- BWHMMNNQKKPAPP-UHFFFAOYSA-L potassium carbonate Chemical compound [K+].[K+].[O-]C([O-])=O BWHMMNNQKKPAPP-UHFFFAOYSA-L 0.000 description 4
- BDERNNFJNOPAEC-UHFFFAOYSA-N propan-1-ol Chemical compound CCCO BDERNNFJNOPAEC-UHFFFAOYSA-N 0.000 description 4
- 229910052683 pyrite Inorganic materials 0.000 description 4
- 239000011347 resin Substances 0.000 description 4
- 229920005989 resin Polymers 0.000 description 4
- HYXGAEYDKFCVMU-UHFFFAOYSA-N scandium(III) oxide Inorganic materials O=[Sc]O[Sc]=O HYXGAEYDKFCVMU-UHFFFAOYSA-N 0.000 description 4
- 229910052950 sphalerite Inorganic materials 0.000 description 4
- 229910000018 strontium carbonate Inorganic materials 0.000 description 4
- 229910001845 yogo sapphire Inorganic materials 0.000 description 4
- 229910000164 yttrium(III) phosphate Inorganic materials 0.000 description 4
- 239000011701 zinc Substances 0.000 description 4
- 229910052984 zinc sulfide Inorganic materials 0.000 description 4
- CSCPPACGZOOCGX-UHFFFAOYSA-N Acetone Chemical compound CC(C)=O CSCPPACGZOOCGX-UHFFFAOYSA-N 0.000 description 3
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 description 3
- 229910004613 CdTe Inorganic materials 0.000 description 3
- 229910052684 Cerium Inorganic materials 0.000 description 3
- PEDCQBHIVMGVHV-UHFFFAOYSA-N Glycerine Chemical compound OCC(O)CO PEDCQBHIVMGVHV-UHFFFAOYSA-N 0.000 description 3
- ZMXDDKWLCZADIW-UHFFFAOYSA-N N,N-Dimethylformamide Chemical compound CN(C)C=O ZMXDDKWLCZADIW-UHFFFAOYSA-N 0.000 description 3
- 101100041681 Takifugu rubripes sand gene Proteins 0.000 description 3
- 229910052776 Thorium Inorganic materials 0.000 description 3
- 229910052946 acanthite Inorganic materials 0.000 description 3
- 150000001412 amines Chemical group 0.000 description 3
- 229910052924 anglesite Inorganic materials 0.000 description 3
- 239000007864 aqueous solution Substances 0.000 description 3
- 229910052964 arsenopyrite Inorganic materials 0.000 description 3
- 159000000009 barium salts Chemical class 0.000 description 3
- 229940073609 bismuth oxychloride Drugs 0.000 description 3
- 125000003178 carboxy group Chemical group [H]OC(*)=O 0.000 description 3
- 229910052923 celestite Inorganic materials 0.000 description 3
- 229910000421 cerium(III) oxide Inorganic materials 0.000 description 3
- QDOXWKRWXJOMAK-UHFFFAOYSA-N chromium(III) oxide Inorganic materials O=[Cr]O[Cr]=O QDOXWKRWXJOMAK-UHFFFAOYSA-N 0.000 description 3
- 229910052956 cinnabar Inorganic materials 0.000 description 3
- 239000000356 contaminant Substances 0.000 description 3
- 229910052802 copper Inorganic materials 0.000 description 3
- 238000006073 displacement reaction Methods 0.000 description 3
- 230000000694 effects Effects 0.000 description 3
- 239000012065 filter cake Substances 0.000 description 3
- 239000000314 lubricant Substances 0.000 description 3
- 229910052748 manganese Inorganic materials 0.000 description 3
- 229910001741 miargyrite Inorganic materials 0.000 description 3
- 239000000178 monomer Substances 0.000 description 3
- 229910052759 nickel Inorganic materials 0.000 description 3
- 229910052757 nitrogen Inorganic materials 0.000 description 3
- BWOROQSFKKODDR-UHFFFAOYSA-N oxobismuth;hydrochloride Chemical compound Cl.[Bi]=O BWOROQSFKKODDR-UHFFFAOYSA-N 0.000 description 3
- 230000000149 penetrating effect Effects 0.000 description 3
- 229920000573 polyethylene Polymers 0.000 description 3
- 230000001376 precipitating effect Effects 0.000 description 3
- 230000008569 process Effects 0.000 description 3
- 229910052968 proustite Inorganic materials 0.000 description 3
- 230000002829 reductive effect Effects 0.000 description 3
- 239000004576 sand Substances 0.000 description 3
- FSJWWSXPIWGYKC-UHFFFAOYSA-M silver;silver;sulfanide Chemical compound [SH-].[Ag].[Ag+] FSJWWSXPIWGYKC-UHFFFAOYSA-M 0.000 description 3
- 239000011734 sodium Substances 0.000 description 3
- 239000003381 stabilizer Substances 0.000 description 3
- 238000005728 strengthening Methods 0.000 description 3
- CIOAGBVUUVVLOB-UHFFFAOYSA-N strontium atom Chemical compound [Sr] CIOAGBVUUVVLOB-UHFFFAOYSA-N 0.000 description 3
- 239000000126 substance Substances 0.000 description 3
- OCGWQDWYSQAFTO-UHFFFAOYSA-N tellanylidenelead Chemical compound [Pb]=[Te] OCGWQDWYSQAFTO-UHFFFAOYSA-N 0.000 description 3
- 239000010936 titanium Substances 0.000 description 3
- FCTBKIHDJGHPPO-UHFFFAOYSA-N uranium dioxide Inorganic materials O=[U]=O FCTBKIHDJGHPPO-UHFFFAOYSA-N 0.000 description 3
- RUDFQVOCFDJEEF-UHFFFAOYSA-N yttrium(III) oxide Inorganic materials [O-2].[O-2].[O-2].[Y+3].[Y+3] RUDFQVOCFDJEEF-UHFFFAOYSA-N 0.000 description 3
- MFEVGQHCNVXMER-UHFFFAOYSA-L 1,3,2$l^{2}-dioxaplumbetan-4-one Chemical compound [Pb+2].[O-]C([O-])=O MFEVGQHCNVXMER-UHFFFAOYSA-L 0.000 description 2
- HRPVXLWXLXDGHG-UHFFFAOYSA-N Acrylamide Chemical compound NC(=O)C=C HRPVXLWXLXDGHG-UHFFFAOYSA-N 0.000 description 2
- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonia chloride Chemical compound [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 description 2
- XKRFYHLGVUSROY-UHFFFAOYSA-N Argon Chemical compound [Ar] XKRFYHLGVUSROY-UHFFFAOYSA-N 0.000 description 2
- RYGMFSIKBFXOCR-UHFFFAOYSA-N Copper Chemical compound [Cu] RYGMFSIKBFXOCR-UHFFFAOYSA-N 0.000 description 2
- 239000005751 Copper oxide Substances 0.000 description 2
- 229910002665 PbTe Inorganic materials 0.000 description 2
- 229920003171 Poly (ethylene oxide) Polymers 0.000 description 2
- 229920002845 Poly(methacrylic acid) Polymers 0.000 description 2
- 239000004952 Polyamide Substances 0.000 description 2
- JUJWROOIHBZHMG-UHFFFAOYSA-N Pyridine Chemical compound C1=CC=NC=C1 JUJWROOIHBZHMG-UHFFFAOYSA-N 0.000 description 2
- XUIMIQQOPSSXEZ-UHFFFAOYSA-N Silicon Chemical compound [Si] XUIMIQQOPSSXEZ-UHFFFAOYSA-N 0.000 description 2
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical compound [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 description 2
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 2
- 229920002125 Sokalan® Polymers 0.000 description 2
- WYURNTSHIVDZCO-UHFFFAOYSA-N Tetrahydrofuran Chemical compound C1CCOC1 WYURNTSHIVDZCO-UHFFFAOYSA-N 0.000 description 2
- ATJFFYVFTNAWJD-UHFFFAOYSA-N Tin Chemical compound [Sn] ATJFFYVFTNAWJD-UHFFFAOYSA-N 0.000 description 2
- 229910052770 Uranium Inorganic materials 0.000 description 2
- HCHKCACWOHOZIP-UHFFFAOYSA-N Zinc Chemical compound [Zn] HCHKCACWOHOZIP-UHFFFAOYSA-N 0.000 description 2
- 230000002378 acidificating effect Effects 0.000 description 2
- 230000004931 aggregating effect Effects 0.000 description 2
- 150000001298 alcohols Chemical class 0.000 description 2
- RWZYAGGXGHYGMB-UHFFFAOYSA-N anthranilic acid Chemical compound NC1=CC=CC=C1C(O)=O RWZYAGGXGHYGMB-UHFFFAOYSA-N 0.000 description 2
- ADCOVFLJGNWWNZ-UHFFFAOYSA-N antimony trioxide Chemical compound O=[Sb]O[Sb]=O ADCOVFLJGNWWNZ-UHFFFAOYSA-N 0.000 description 2
- 229910052785 arsenic Inorganic materials 0.000 description 2
- 229910052788 barium Inorganic materials 0.000 description 2
- DSAJWYNOEDNPEQ-UHFFFAOYSA-N barium atom Chemical compound [Ba] DSAJWYNOEDNPEQ-UHFFFAOYSA-N 0.000 description 2
- 230000002902 bimodal effect Effects 0.000 description 2
- 239000011230 binding agent Substances 0.000 description 2
- 229920001400 block copolymer Polymers 0.000 description 2
- 229910052972 bournonite Inorganic materials 0.000 description 2
- 238000001354 calcination Methods 0.000 description 2
- WUKWITHWXAAZEY-UHFFFAOYSA-L calcium difluoride Chemical compound [F-].[F-].[Ca+2] WUKWITHWXAAZEY-UHFFFAOYSA-L 0.000 description 2
- ZCCIPPOKBCJFDN-UHFFFAOYSA-N calcium nitrate Chemical compound [Ca+2].[O-][N+]([O-])=O.[O-][N+]([O-])=O ZCCIPPOKBCJFDN-UHFFFAOYSA-N 0.000 description 2
- BRPQOXSCLDDYGP-UHFFFAOYSA-N calcium oxide Chemical compound [O-2].[Ca+2] BRPQOXSCLDDYGP-UHFFFAOYSA-N 0.000 description 2
- 150000004649 carbonic acid derivatives Chemical class 0.000 description 2
- 239000003638 chemical reducing agent Substances 0.000 description 2
- ZCDOYSPFYFSLEW-UHFFFAOYSA-N chromate(2-) Chemical class [O-][Cr]([O-])(=O)=O ZCDOYSPFYFSLEW-UHFFFAOYSA-N 0.000 description 2
- 239000011651 chromium Substances 0.000 description 2
- 239000004927 clay Substances 0.000 description 2
- 239000008199 coating composition Substances 0.000 description 2
- 229910017052 cobalt Inorganic materials 0.000 description 2
- 239000010941 cobalt Substances 0.000 description 2
- GUTLYIVDDKVIGB-UHFFFAOYSA-N cobalt atom Chemical compound [Co] GUTLYIVDDKVIGB-UHFFFAOYSA-N 0.000 description 2
- 238000010276 construction Methods 0.000 description 2
- 229920001577 copolymer Polymers 0.000 description 2
- 229910000431 copper oxide Inorganic materials 0.000 description 2
- 239000013078 crystal Substances 0.000 description 2
- 238000005520 cutting process Methods 0.000 description 2
- 230000000593 degrading effect Effects 0.000 description 2
- 235000014113 dietary fatty acids Nutrition 0.000 description 2
- 239000003792 electrolyte Substances 0.000 description 2
- 229910052971 enargite Inorganic materials 0.000 description 2
- 230000003628 erosive effect Effects 0.000 description 2
- 150000002170 ethers Chemical class 0.000 description 2
- RRAFCDWBNXTKKO-UHFFFAOYSA-N eugenol Chemical compound COC1=CC(CC=C)=CC=C1O RRAFCDWBNXTKKO-UHFFFAOYSA-N 0.000 description 2
- 239000000194 fatty acid Substances 0.000 description 2
- 229930195729 fatty acid Natural products 0.000 description 2
- 150000004665 fatty acids Chemical class 0.000 description 2
- 229910052949 galena Inorganic materials 0.000 description 2
- 235000011187 glycerol Nutrition 0.000 description 2
- 150000002334 glycols Chemical class 0.000 description 2
- 239000010931 gold Substances 0.000 description 2
- LHGVFZTZFXWLCP-UHFFFAOYSA-N guaiacol Chemical compound COC1=CC=CC=C1O LHGVFZTZFXWLCP-UHFFFAOYSA-N 0.000 description 2
- 239000003112 inhibitor Substances 0.000 description 2
- 238000002955 isolation Methods 0.000 description 2
- AXZKOIWUVFPNLO-UHFFFAOYSA-N magnesium;oxygen(2-) Chemical compound [O-2].[Mg+2] AXZKOIWUVFPNLO-UHFFFAOYSA-N 0.000 description 2
- WPBNNNQJVZRUHP-UHFFFAOYSA-L manganese(2+);methyl n-[[2-(methoxycarbonylcarbamothioylamino)phenyl]carbamothioyl]carbamate;n-[2-(sulfidocarbothioylamino)ethyl]carbamodithioate Chemical compound [Mn+2].[S-]C(=S)NCCNC([S-])=S.COC(=O)NC(=S)NC1=CC=CC=C1NC(=S)NC(=O)OC WPBNNNQJVZRUHP-UHFFFAOYSA-L 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 230000005012 migration Effects 0.000 description 2
- 238000013508 migration Methods 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 229910052758 niobium Inorganic materials 0.000 description 2
- GNRSAWUEBMWBQH-UHFFFAOYSA-N oxonickel Chemical compound [Ni]=O GNRSAWUEBMWBQH-UHFFFAOYSA-N 0.000 description 2
- RVTZCBVAJQQJTK-UHFFFAOYSA-N oxygen(2-);zirconium(4+) Chemical compound [O-2].[O-2].[Zr+4] RVTZCBVAJQQJTK-UHFFFAOYSA-N 0.000 description 2
- 229910001738 pearceite Inorganic materials 0.000 description 2
- 230000035699 permeability Effects 0.000 description 2
- 239000012071 phase Substances 0.000 description 2
- 239000006187 pill Substances 0.000 description 2
- 229920002647 polyamide Polymers 0.000 description 2
- 239000010695 polyglycol Substances 0.000 description 2
- 229920000151 polyglycol Polymers 0.000 description 2
- SCVFZCLFOSHCOH-UHFFFAOYSA-M potassium acetate Chemical compound [K+].CC([O-])=O SCVFZCLFOSHCOH-UHFFFAOYSA-M 0.000 description 2
- 229910000027 potassium carbonate Inorganic materials 0.000 description 2
- FGIUAXJPYTZDNR-UHFFFAOYSA-N potassium nitrate Chemical compound [K+].[O-][N+]([O-])=O FGIUAXJPYTZDNR-UHFFFAOYSA-N 0.000 description 2
- 239000002244 precipitate Substances 0.000 description 2
- 239000000047 product Substances 0.000 description 2
- 229910052967 pyrargyrite Inorganic materials 0.000 description 2
- YGSDEFSMJLZEOE-UHFFFAOYSA-N salicylic acid Chemical compound OC(=O)C1=CC=CC=C1O YGSDEFSMJLZEOE-UHFFFAOYSA-N 0.000 description 2
- 150000004760 silicates Chemical class 0.000 description 2
- 239000010703 silicon Substances 0.000 description 2
- 229910052710 silicon Inorganic materials 0.000 description 2
- VWDWKYIASSYTQR-UHFFFAOYSA-N sodium nitrate Chemical compound [Na+].[O-][N+]([O-])=O VWDWKYIASSYTQR-UHFFFAOYSA-N 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- 229910052959 stibnite Inorganic materials 0.000 description 2
- 230000000638 stimulation Effects 0.000 description 2
- 150000003467 sulfuric acid derivatives Chemical class 0.000 description 2
- 239000000725 suspension Substances 0.000 description 2
- 238000003786 synthesis reaction Methods 0.000 description 2
- 229910052715 tantalum Inorganic materials 0.000 description 2
- 229910052841 tephroite Inorganic materials 0.000 description 2
- 229910052847 thorite Inorganic materials 0.000 description 2
- 229910052718 tin Inorganic materials 0.000 description 2
- 239000011135 tin Substances 0.000 description 2
- ITRNXVSDJBHYNJ-UHFFFAOYSA-N tungsten disulfide Chemical compound S=[W]=S ITRNXVSDJBHYNJ-UHFFFAOYSA-N 0.000 description 2
- 229910052725 zinc Inorganic materials 0.000 description 2
- VNDYJBBGRKZCSX-UHFFFAOYSA-L zinc bromide Chemical compound Br[Zn]Br VNDYJBBGRKZCSX-UHFFFAOYSA-L 0.000 description 2
- 229910001928 zirconium oxide Inorganic materials 0.000 description 2
- GFQYVLUOOAAOGM-UHFFFAOYSA-N zirconium(iv) silicate Chemical compound [Zr+4].[O-][Si]([O-])([O-])[O-] GFQYVLUOOAAOGM-UHFFFAOYSA-N 0.000 description 2
- 239000004711 α-olefin Substances 0.000 description 2
- PUPZLCDOIYMWBV-UHFFFAOYSA-N (+/-)-1,3-Butanediol Chemical compound CC(O)CCO PUPZLCDOIYMWBV-UHFFFAOYSA-N 0.000 description 1
- CCVYRRGZDBSHFU-UHFFFAOYSA-N (2-hydroxyphenyl)acetic acid Chemical compound OC(=O)CC1=CC=CC=C1O CCVYRRGZDBSHFU-UHFFFAOYSA-N 0.000 description 1
- MSBGPEACXKBQSX-UHFFFAOYSA-N (4-fluorophenyl) carbonochloridate Chemical compound FC1=CC=C(OC(Cl)=O)C=C1 MSBGPEACXKBQSX-UHFFFAOYSA-N 0.000 description 1
- WRIDQFICGBMAFQ-UHFFFAOYSA-N (E)-8-Octadecenoic acid Natural products CCCCCCCCCC=CCCCCCCC(O)=O WRIDQFICGBMAFQ-UHFFFAOYSA-N 0.000 description 1
- GEYOCULIXLDCMW-UHFFFAOYSA-N 1,2-phenylenediamine Chemical compound NC1=CC=CC=C1N GEYOCULIXLDCMW-UHFFFAOYSA-N 0.000 description 1
- KEQXNNJHMWSZHK-UHFFFAOYSA-L 1,3,2,4$l^{2}-dioxathiaplumbetane 2,2-dioxide Chemical compound [Pb+2].[O-]S([O-])(=O)=O KEQXNNJHMWSZHK-UHFFFAOYSA-L 0.000 description 1
- OHBKNWDVVSUTRV-UHFFFAOYSA-N 1-(prop-2-enoylamino)propane-2-sulfonic acid Chemical compound OS(=O)(=O)C(C)CNC(=O)C=C OHBKNWDVVSUTRV-UHFFFAOYSA-N 0.000 description 1
- IVORCBKUUYGUOL-UHFFFAOYSA-N 1-ethynyl-2,4-dimethoxybenzene Chemical compound COC1=CC=C(C#C)C(OC)=C1 IVORCBKUUYGUOL-UHFFFAOYSA-N 0.000 description 1
- SMZOUWXMTYCWNB-UHFFFAOYSA-N 2-(2-methoxy-5-methylphenyl)ethanamine Chemical compound COC1=CC=C(C)C=C1CCN SMZOUWXMTYCWNB-UHFFFAOYSA-N 0.000 description 1
- PAWQVTBBRAZDMG-UHFFFAOYSA-N 2-(3-bromo-2-fluorophenyl)acetic acid Chemical compound OC(=O)CC1=CC=CC(Br)=C1F PAWQVTBBRAZDMG-UHFFFAOYSA-N 0.000 description 1
- JAHNSTQSQJOJLO-UHFFFAOYSA-N 2-(3-fluorophenyl)-1h-imidazole Chemical compound FC1=CC=CC(C=2NC=CN=2)=C1 JAHNSTQSQJOJLO-UHFFFAOYSA-N 0.000 description 1
- NIXOWILDQLNWCW-UHFFFAOYSA-N 2-Propenoic acid Natural products OC(=O)C=C NIXOWILDQLNWCW-UHFFFAOYSA-N 0.000 description 1
- CDAWCLOXVUBKRW-UHFFFAOYSA-N 2-aminophenol Chemical compound NC1=CC=CC=C1O CDAWCLOXVUBKRW-UHFFFAOYSA-N 0.000 description 1
- FRWYFWZENXDZMU-UHFFFAOYSA-N 2-iodoquinoline Chemical compound C1=CC=CC2=NC(I)=CC=C21 FRWYFWZENXDZMU-UHFFFAOYSA-N 0.000 description 1
- AGBXYHCHUYARJY-UHFFFAOYSA-N 2-phenylethenesulfonic acid Chemical compound OS(=O)(=O)C=CC1=CC=CC=C1 AGBXYHCHUYARJY-UHFFFAOYSA-N 0.000 description 1
- LQJBNNIYVWPHFW-UHFFFAOYSA-N 20:1omega9c fatty acid Natural products CCCCCCCCCCC=CCCCCCCCC(O)=O LQJBNNIYVWPHFW-UHFFFAOYSA-N 0.000 description 1
- BSYNRYMUTXBXSQ-FOQJRBATSA-N 59096-14-9 Chemical compound CC(=O)OC1=CC=CC=C1[14C](O)=O BSYNRYMUTXBXSQ-FOQJRBATSA-N 0.000 description 1
- HCJMNOSIAGSZBM-UHFFFAOYSA-N 6-methylsalicylic acid Chemical compound CC1=CC=CC(O)=C1C(O)=O HCJMNOSIAGSZBM-UHFFFAOYSA-N 0.000 description 1
- QSBYPNXLFMSGKH-UHFFFAOYSA-N 9-Heptadecensaeure Natural products CCCCCCCC=CCCCCCCCC(O)=O QSBYPNXLFMSGKH-UHFFFAOYSA-N 0.000 description 1
- 229910002688 Ag2Te Inorganic materials 0.000 description 1
- USFZMSVCRYTOJT-UHFFFAOYSA-N Ammonium acetate Chemical compound N.CC(O)=O USFZMSVCRYTOJT-UHFFFAOYSA-N 0.000 description 1
- 239000005695 Ammonium acetate Substances 0.000 description 1
- 229910052582 BN Inorganic materials 0.000 description 1
- LSNNMFCWUKXFEE-UHFFFAOYSA-M Bisulfite Chemical compound OS([O-])=O LSNNMFCWUKXFEE-UHFFFAOYSA-M 0.000 description 1
- PZNSFCLAULLKQX-UHFFFAOYSA-N Boron nitride Chemical compound N#B PZNSFCLAULLKQX-UHFFFAOYSA-N 0.000 description 1
- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 description 1
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 1
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 1
- LZZYPRNAOMGNLH-UHFFFAOYSA-M Cetrimonium bromide Chemical compound [Br-].CCCCCCCCCCCCCCCC[N+](C)(C)C LZZYPRNAOMGNLH-UHFFFAOYSA-M 0.000 description 1
- NPBVQXIMTZKSBA-UHFFFAOYSA-N Chavibetol Natural products COC1=CC=C(CC=C)C=C1O NPBVQXIMTZKSBA-UHFFFAOYSA-N 0.000 description 1
- VYZAMTAEIAYCRO-UHFFFAOYSA-N Chromium Chemical compound [Cr] VYZAMTAEIAYCRO-UHFFFAOYSA-N 0.000 description 1
- KRKNYBCHXYNGOX-UHFFFAOYSA-K Citrate Chemical compound [O-]C(=O)CC(O)(CC([O-])=O)C([O-])=O KRKNYBCHXYNGOX-UHFFFAOYSA-K 0.000 description 1
- 241000257465 Echinoidea Species 0.000 description 1
- 239000004593 Epoxy Substances 0.000 description 1
- IAYPIBMASNFSPL-UHFFFAOYSA-N Ethylene oxide Chemical compound C1CO1 IAYPIBMASNFSPL-UHFFFAOYSA-N 0.000 description 1
- 239000005770 Eugenol Substances 0.000 description 1
- MBMLMWLHJBBADN-UHFFFAOYSA-N Ferrous sulfide Chemical compound [Fe]=S MBMLMWLHJBBADN-UHFFFAOYSA-N 0.000 description 1
- 239000005909 Kieselgur Substances 0.000 description 1
- FYYHWMGAXLPEAU-UHFFFAOYSA-N Magnesium Chemical compound [Mg] FYYHWMGAXLPEAU-UHFFFAOYSA-N 0.000 description 1
- 241001676573 Minium Species 0.000 description 1
- WHNWPMSKXPGLAX-UHFFFAOYSA-N N-Vinyl-2-pyrrolidone Chemical compound C=CN1CCCC1=O WHNWPMSKXPGLAX-UHFFFAOYSA-N 0.000 description 1
- QSACCXVHEVWNMX-UHFFFAOYSA-N N-acetylanthranilic acid Chemical compound CC(=O)NC1=CC=CC=C1C(O)=O QSACCXVHEVWNMX-UHFFFAOYSA-N 0.000 description 1
- 239000005642 Oleic acid Substances 0.000 description 1
- ZQPPMHVWECSIRJ-UHFFFAOYSA-N Oleic acid Natural products CCCCCCCCC=CCCCCCCCC(O)=O ZQPPMHVWECSIRJ-UHFFFAOYSA-N 0.000 description 1
- 229910020486 P2VP Inorganic materials 0.000 description 1
- 229910018828 PO3H2 Inorganic materials 0.000 description 1
- 229910019142 PO4 Inorganic materials 0.000 description 1
- 239000004743 Polypropylene Substances 0.000 description 1
- OFOBLEOULBTSOW-UHFFFAOYSA-N Propanedioic acid Natural products OC(=O)CC(O)=O OFOBLEOULBTSOW-UHFFFAOYSA-N 0.000 description 1
- GOOHAUXETOMSMM-UHFFFAOYSA-N Propylene oxide Chemical compound CC1CO1 GOOHAUXETOMSMM-UHFFFAOYSA-N 0.000 description 1
- UVMRYBDEERADNV-UHFFFAOYSA-N Pseudoeugenol Natural products COC1=CC(C(C)=C)=CC=C1O UVMRYBDEERADNV-UHFFFAOYSA-N 0.000 description 1
- 229910006069 SO3H Inorganic materials 0.000 description 1
- BLRPTPMANUNPDV-UHFFFAOYSA-N Silane Chemical group [SiH4] BLRPTPMANUNPDV-UHFFFAOYSA-N 0.000 description 1
- BQCADISMDOOEFD-UHFFFAOYSA-N Silver Chemical compound [Ag] BQCADISMDOOEFD-UHFFFAOYSA-N 0.000 description 1
- 229910021607 Silver chloride Inorganic materials 0.000 description 1
- VMHLLURERBWHNL-UHFFFAOYSA-M Sodium acetate Chemical compound [Na+].CC([O-])=O VMHLLURERBWHNL-UHFFFAOYSA-M 0.000 description 1
- 239000004280 Sodium formate Substances 0.000 description 1
- DBMJMQXJHONAFJ-UHFFFAOYSA-M Sodium laurylsulphate Chemical compound [Na+].CCCCCCCCCCCCOS([O-])(=O)=O DBMJMQXJHONAFJ-UHFFFAOYSA-M 0.000 description 1
- ABBQHOQBGMUPJH-UHFFFAOYSA-M Sodium salicylate Chemical compound [Na+].OC1=CC=CC=C1C([O-])=O ABBQHOQBGMUPJH-UHFFFAOYSA-M 0.000 description 1
- UCKMPCXJQFINFW-UHFFFAOYSA-N Sulphide Chemical compound [S-2] UCKMPCXJQFINFW-UHFFFAOYSA-N 0.000 description 1
- 241001455273 Tetrapoda Species 0.000 description 1
- 229920002359 Tetronic® Polymers 0.000 description 1
- RTAQQCXQSZGOHL-UHFFFAOYSA-N Titanium Chemical compound [Ti] RTAQQCXQSZGOHL-UHFFFAOYSA-N 0.000 description 1
- WGLPBDUCMAPZCE-UHFFFAOYSA-N Trioxochromium Chemical compound O=[Cr](=O)=O WGLPBDUCMAPZCE-UHFFFAOYSA-N 0.000 description 1
- 229910021542 Vanadium(IV) oxide Inorganic materials 0.000 description 1
- XTXRWKRVRITETP-UHFFFAOYSA-N Vinyl acetate Chemical compound CC(=O)OC=C XTXRWKRVRITETP-UHFFFAOYSA-N 0.000 description 1
- FMRLDPWIRHBCCC-UHFFFAOYSA-L Zinc carbonate Chemical compound [Zn+2].[O-]C([O-])=O FMRLDPWIRHBCCC-UHFFFAOYSA-L 0.000 description 1
- QCWXUUIWCKQGHC-UHFFFAOYSA-N Zirconium Chemical compound [Zr] QCWXUUIWCKQGHC-UHFFFAOYSA-N 0.000 description 1
- XHCLAFWTIXFWPH-UHFFFAOYSA-N [O-2].[O-2].[O-2].[O-2].[O-2].[V+5].[V+5] Chemical compound [O-2].[O-2].[O-2].[O-2].[O-2].[V+5].[V+5] XHCLAFWTIXFWPH-UHFFFAOYSA-N 0.000 description 1
- QUEDYRXQWSDKKG-UHFFFAOYSA-M [O-2].[O-2].[V+5].[OH-] Chemical compound [O-2].[O-2].[V+5].[OH-] QUEDYRXQWSDKKG-UHFFFAOYSA-M 0.000 description 1
- 150000001242 acetic acid derivatives Chemical class 0.000 description 1
- 150000007513 acids Chemical class 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 239000008186 active pharmaceutical agent Substances 0.000 description 1
- 239000003570 air Substances 0.000 description 1
- 150000001335 aliphatic alkanes Chemical class 0.000 description 1
- 229910000288 alkali metal carbonate Inorganic materials 0.000 description 1
- 150000008041 alkali metal carbonates Chemical class 0.000 description 1
- 150000001336 alkenes Chemical class 0.000 description 1
- 150000003973 alkyl amines Chemical class 0.000 description 1
- 150000008055 alkyl aryl sulfonates Chemical class 0.000 description 1
- 125000000217 alkyl group Chemical group 0.000 description 1
- 150000001343 alkyl silanes Chemical class 0.000 description 1
- 229940045714 alkyl sulfonate alkylating agent Drugs 0.000 description 1
- 150000008052 alkyl sulfonates Chemical class 0.000 description 1
- 230000004075 alteration Effects 0.000 description 1
- 229910052782 aluminium Inorganic materials 0.000 description 1
- XAGFODPZIPBFFR-UHFFFAOYSA-N aluminium Chemical compound [Al] XAGFODPZIPBFFR-UHFFFAOYSA-N 0.000 description 1
- 235000019257 ammonium acetate Nutrition 0.000 description 1
- 229940043376 ammonium acetate Drugs 0.000 description 1
- SWLVFNYSXGMGBS-UHFFFAOYSA-N ammonium bromide Chemical compound [NH4+].[Br-] SWLVFNYSXGMGBS-UHFFFAOYSA-N 0.000 description 1
- 235000019270 ammonium chloride Nutrition 0.000 description 1
- BFNBIHQBYMNNAN-UHFFFAOYSA-N ammonium sulfate Chemical compound N.N.OS(O)(=O)=O BFNBIHQBYMNNAN-UHFFFAOYSA-N 0.000 description 1
- 229910052921 ammonium sulfate Inorganic materials 0.000 description 1
- 235000011130 ammonium sulphate Nutrition 0.000 description 1
- 229910052849 andalusite Inorganic materials 0.000 description 1
- 125000000129 anionic group Chemical group 0.000 description 1
- 239000002518 antifoaming agent Substances 0.000 description 1
- 229910052787 antimony Inorganic materials 0.000 description 1
- WATWJIUSRGPENY-UHFFFAOYSA-N antimony atom Chemical compound [Sb] WATWJIUSRGPENY-UHFFFAOYSA-N 0.000 description 1
- 229910052786 argon Inorganic materials 0.000 description 1
- UIFOTCALDQIDTI-UHFFFAOYSA-N arsanylidynenickel Chemical compound [As]#[Ni] UIFOTCALDQIDTI-UHFFFAOYSA-N 0.000 description 1
- MJLGNAGLHAQFHV-UHFFFAOYSA-N arsenopyrite Chemical compound [S-2].[Fe+3].[As-] MJLGNAGLHAQFHV-UHFFFAOYSA-N 0.000 description 1
- AYJRCSIUFZENHW-DEQYMQKBSA-L barium(2+);oxomethanediolate Chemical compound [Ba+2].[O-][14C]([O-])=O AYJRCSIUFZENHW-DEQYMQKBSA-L 0.000 description 1
- 239000003139 biocide Substances 0.000 description 1
- 229940036348 bismuth carbonate Drugs 0.000 description 1
- 229910000416 bismuth oxide Inorganic materials 0.000 description 1
- 229910052796 boron Inorganic materials 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- 150000001649 bromium compounds Chemical class 0.000 description 1
- CQEYYJKEWSMYFG-UHFFFAOYSA-N butyl acrylate Chemical compound CCCCOC(=O)C=C CQEYYJKEWSMYFG-UHFFFAOYSA-N 0.000 description 1
- 229910052793 cadmium Inorganic materials 0.000 description 1
- BDOSMKKIYDKNTQ-UHFFFAOYSA-N cadmium atom Chemical compound [Cd] BDOSMKKIYDKNTQ-UHFFFAOYSA-N 0.000 description 1
- ATZQZZAXOPPAAQ-UHFFFAOYSA-M caesium formate Chemical compound [Cs+].[O-]C=O ATZQZZAXOPPAAQ-UHFFFAOYSA-M 0.000 description 1
- VSGNNIFQASZAOI-UHFFFAOYSA-L calcium acetate Chemical compound [Ca+2].CC([O-])=O.CC([O-])=O VSGNNIFQASZAOI-UHFFFAOYSA-L 0.000 description 1
- 239000001639 calcium acetate Substances 0.000 description 1
- 235000011092 calcium acetate Nutrition 0.000 description 1
- 229960005147 calcium acetate Drugs 0.000 description 1
- 229910001622 calcium bromide Inorganic materials 0.000 description 1
- 239000001110 calcium chloride Substances 0.000 description 1
- 229910001628 calcium chloride Inorganic materials 0.000 description 1
- WGEFECGEFUFIQW-UHFFFAOYSA-L calcium dibromide Chemical compound [Ca+2].[Br-].[Br-] WGEFECGEFUFIQW-UHFFFAOYSA-L 0.000 description 1
- 229910001634 calcium fluoride Inorganic materials 0.000 description 1
- 229940075397 calomel Drugs 0.000 description 1
- 125000002091 cationic group Chemical group 0.000 description 1
- ZMIGMASIKSOYAM-UHFFFAOYSA-N cerium Chemical compound [Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce][Ce] ZMIGMASIKSOYAM-UHFFFAOYSA-N 0.000 description 1
- 229910000420 cerium oxide Inorganic materials 0.000 description 1
- IKNAJTLCCWPIQD-UHFFFAOYSA-K cerium(3+);lanthanum(3+);neodymium(3+);oxygen(2-);phosphate Chemical compound [O-2].[La+3].[Ce+3].[Nd+3].[O-]P([O-])([O-])=O IKNAJTLCCWPIQD-UHFFFAOYSA-K 0.000 description 1
- 229910052947 chalcocite Inorganic materials 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 150000001805 chlorine compounds Chemical class 0.000 description 1
- 229910052804 chromium Inorganic materials 0.000 description 1
- 229910000423 chromium oxide Inorganic materials 0.000 description 1
- JOPOVCBBYLSVDA-UHFFFAOYSA-N chromium(6+) Chemical class [Cr+6] JOPOVCBBYLSVDA-UHFFFAOYSA-N 0.000 description 1
- 150000001860 citric acid derivatives Chemical class 0.000 description 1
- 229910052963 cobaltite Inorganic materials 0.000 description 1
- 230000001276 controlling effect Effects 0.000 description 1
- PTVDYARBVCBHSL-UHFFFAOYSA-N copper;hydrate Chemical compound O.[Cu] PTVDYARBVCBHSL-UHFFFAOYSA-N 0.000 description 1
- LBJNMUFDOHXDFG-UHFFFAOYSA-N copper;hydrate Chemical compound O.[Cu].[Cu] LBJNMUFDOHXDFG-UHFFFAOYSA-N 0.000 description 1
- KYRUBSWVBPYWEF-UHFFFAOYSA-N copper;iron;sulfane;tin Chemical compound S.S.S.S.[Fe].[Cu].[Cu].[Sn] KYRUBSWVBPYWEF-UHFFFAOYSA-N 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 239000010431 corundum Substances 0.000 description 1
- 239000003431 cross linking reagent Substances 0.000 description 1
- 150000001924 cycloalkanes Chemical class 0.000 description 1
- 230000001419 dependent effect Effects 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 239000010432 diamond Substances 0.000 description 1
- 229910003460 diamond Inorganic materials 0.000 description 1
- TYIXMATWDRGMPF-UHFFFAOYSA-N dibismuth;oxygen(2-) Chemical compound [O-2].[O-2].[O-2].[Bi+3].[Bi+3] TYIXMATWDRGMPF-UHFFFAOYSA-N 0.000 description 1
- FWIZHMQARNODNX-UHFFFAOYSA-L dibismuth;oxygen(2-);carbonate Chemical compound [O-2].[O-2].[Bi+3].[Bi+3].[O-]C([O-])=O FWIZHMQARNODNX-UHFFFAOYSA-L 0.000 description 1
- GMZOPRQQINFLPQ-UHFFFAOYSA-H dibismuth;tricarbonate Chemical compound [Bi+3].[Bi+3].[O-]C([O-])=O.[O-]C([O-])=O.[O-]C([O-])=O GMZOPRQQINFLPQ-UHFFFAOYSA-H 0.000 description 1
- ZOMNIUBKTOKEHS-UHFFFAOYSA-L dimercury dichloride Chemical compound Cl[Hg][Hg]Cl ZOMNIUBKTOKEHS-UHFFFAOYSA-L 0.000 description 1
- 229910001873 dinitrogen Inorganic materials 0.000 description 1
- ZXOKVTWPEIAYAB-UHFFFAOYSA-N dioxido(oxo)tungsten Chemical compound [O-][W]([O-])=O ZXOKVTWPEIAYAB-UHFFFAOYSA-N 0.000 description 1
- 239000006185 dispersion Substances 0.000 description 1
- 238000004090 dissolution Methods 0.000 description 1
- 229910000514 dolomite Inorganic materials 0.000 description 1
- 239000010459 dolomite Substances 0.000 description 1
- 239000003995 emulsifying agent Substances 0.000 description 1
- 230000002708 enhancing effect Effects 0.000 description 1
- 125000003700 epoxy group Chemical group 0.000 description 1
- IZRICFNDFRWBBG-UHFFFAOYSA-N ethenesulfonic acid;3-hydroxypropyl prop-2-enoate Chemical compound OS(=O)(=O)C=C.OCCCOC(=O)C=C IZRICFNDFRWBBG-UHFFFAOYSA-N 0.000 description 1
- RTZKZFJDLAIYFH-UHFFFAOYSA-N ether Substances CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 description 1
- 125000001033 ether group Chemical group 0.000 description 1
- 229960002217 eugenol Drugs 0.000 description 1
- 150000002191 fatty alcohols Chemical class 0.000 description 1
- 239000000945 filler Substances 0.000 description 1
- 238000007667 floating Methods 0.000 description 1
- 150000002222 fluorine compounds Chemical class 0.000 description 1
- 239000010436 fluorite Substances 0.000 description 1
- 150000004675 formic acid derivatives Chemical class 0.000 description 1
- 239000013505 freshwater Substances 0.000 description 1
- 230000004927 fusion Effects 0.000 description 1
- 229910001676 gahnite Inorganic materials 0.000 description 1
- 229910001677 galaxite Inorganic materials 0.000 description 1
- 239000003349 gelling agent Substances 0.000 description 1
- 150000002314 glycerols Chemical class 0.000 description 1
- PCHJSUWPFVWCPO-UHFFFAOYSA-N gold Chemical compound [Au] PCHJSUWPFVWCPO-UHFFFAOYSA-N 0.000 description 1
- 229910052737 gold Inorganic materials 0.000 description 1
- 229910002804 graphite Inorganic materials 0.000 description 1
- 239000010439 graphite Substances 0.000 description 1
- 229960001867 guaiacol Drugs 0.000 description 1
- 229910001385 heavy metal Inorganic materials 0.000 description 1
- 239000001307 helium Substances 0.000 description 1
- 229910052734 helium Inorganic materials 0.000 description 1
- SWQJXJOGLNCZEY-UHFFFAOYSA-N helium atom Chemical compound [He] SWQJXJOGLNCZEY-UHFFFAOYSA-N 0.000 description 1
- 239000011019 hematite Substances 0.000 description 1
- 229910052595 hematite Inorganic materials 0.000 description 1
- 239000008240 homogeneous mixture Substances 0.000 description 1
- 229920001519 homopolymer Polymers 0.000 description 1
- 239000011396 hydraulic cement Substances 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 230000002209 hydrophobic effect Effects 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-M hydroxide Chemical compound [OH-] XLYOFNOQVPJJNP-UHFFFAOYSA-M 0.000 description 1
- 150000004679 hydroxides Chemical class 0.000 description 1
- 229910052867 ilvaite Inorganic materials 0.000 description 1
- 238000010348 incorporation Methods 0.000 description 1
- 230000002401 inhibitory effect Effects 0.000 description 1
- 229910010272 inorganic material Inorganic materials 0.000 description 1
- 239000011147 inorganic material Substances 0.000 description 1
- 150000004694 iodide salts Chemical class 0.000 description 1
- LIKBJVNGSGBSGK-UHFFFAOYSA-N iron(3+);oxygen(2-) Chemical compound [O-2].[O-2].[O-2].[Fe+3].[Fe+3] LIKBJVNGSGBSGK-UHFFFAOYSA-N 0.000 description 1
- YDZQQRWRVYGNER-UHFFFAOYSA-N iron;titanium;trihydrate Chemical compound O.O.O.[Ti].[Fe] YDZQQRWRVYGNER-UHFFFAOYSA-N 0.000 description 1
- QXJSBBXBKPUZAA-UHFFFAOYSA-N isooleic acid Natural products CCCCCCCC=CCCCCCCCCC(O)=O QXJSBBXBKPUZAA-UHFFFAOYSA-N 0.000 description 1
- 229910052973 jamesonite Inorganic materials 0.000 description 1
- TYYHXOUGFIRONY-UHFFFAOYSA-D lead(2+);trioxido(oxo)-$l^{5}-arsane;chloride Chemical compound [Cl-].[Pb+2].[Pb+2].[Pb+2].[Pb+2].[Pb+2].[O-][As]([O-])([O-])=O.[O-][As]([O-])([O-])=O.[O-][As]([O-])([O-])=O TYYHXOUGFIRONY-UHFFFAOYSA-D 0.000 description 1
- XCAUINMIESBTBL-UHFFFAOYSA-N lead(ii) sulfide Chemical compound [Pb]=S XCAUINMIESBTBL-UHFFFAOYSA-N 0.000 description 1
- 239000007791 liquid phase Substances 0.000 description 1
- IQPNAANSBPBGFQ-UHFFFAOYSA-N luteolin Chemical compound C=1C(O)=CC(O)=C(C(C=2)=O)C=1OC=2C1=CC=C(O)C(O)=C1 IQPNAANSBPBGFQ-UHFFFAOYSA-N 0.000 description 1
- VTHJTEIRLNZDEV-UHFFFAOYSA-L magnesium dihydroxide Chemical compound [OH-].[OH-].[Mg+2] VTHJTEIRLNZDEV-UHFFFAOYSA-L 0.000 description 1
- 239000000347 magnesium hydroxide Substances 0.000 description 1
- 229910001862 magnesium hydroxide Inorganic materials 0.000 description 1
- VZCYOOQTPOCHFL-UPHRSURJSA-N maleic acid Chemical compound OC(=O)\C=C/C(O)=O VZCYOOQTPOCHFL-UPHRSURJSA-N 0.000 description 1
- 239000011976 maleic acid Substances 0.000 description 1
- FPYJFEHAWHCUMM-UHFFFAOYSA-N maleic anhydride Chemical compound O=C1OC(=O)C=C1 FPYJFEHAWHCUMM-UHFFFAOYSA-N 0.000 description 1
- LQKOJSSIKZIEJC-UHFFFAOYSA-N manganese(2+) oxygen(2-) Chemical compound [O-2].[O-2].[O-2].[O-2].[Mn+2].[Mn+2].[Mn+2].[Mn+2] LQKOJSSIKZIEJC-UHFFFAOYSA-N 0.000 description 1
- PPNAOCWZXJOHFK-UHFFFAOYSA-N manganese(2+);oxygen(2-) Chemical compound [O-2].[Mn+2] PPNAOCWZXJOHFK-UHFFFAOYSA-N 0.000 description 1
- QSHDDOUJBYECFT-UHFFFAOYSA-N mercury Chemical compound [Hg] QSHDDOUJBYECFT-UHFFFAOYSA-N 0.000 description 1
- 229910052753 mercury Inorganic materials 0.000 description 1
- 229910052751 metal Inorganic materials 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- FQPSGWSUVKBHSU-UHFFFAOYSA-N methacrylamide Chemical compound CC(=C)C(N)=O FQPSGWSUVKBHSU-UHFFFAOYSA-N 0.000 description 1
- NMJORVOYSJLJGU-UHFFFAOYSA-N methane clathrate Chemical compound C.C.C.C.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O NMJORVOYSJLJGU-UHFFFAOYSA-N 0.000 description 1
- ONWPLBKWMAUFGZ-UHFFFAOYSA-N methyl 2-acetyloxybenzoate Chemical compound COC(=O)C1=CC=CC=C1OC(C)=O ONWPLBKWMAUFGZ-UHFFFAOYSA-N 0.000 description 1
- XJRBAMWJDBPFIM-UHFFFAOYSA-N methyl vinyl ether Chemical compound COC=C XJRBAMWJDBPFIM-UHFFFAOYSA-N 0.000 description 1
- LVHBHZANLOWSRM-UHFFFAOYSA-N methylenebutanedioic acid Natural products OC(=O)CC(=C)C(O)=O LVHBHZANLOWSRM-UHFFFAOYSA-N 0.000 description 1
- 239000002480 mineral oil Substances 0.000 description 1
- 150000007522 mineralic acids Chemical class 0.000 description 1
- 230000000116 mitigating effect Effects 0.000 description 1
- 229910000476 molybdenum oxide Inorganic materials 0.000 description 1
- AQRDGTBNWBTFKJ-UHFFFAOYSA-N molybdenum;dihydrate Chemical compound O.O.[Mo] AQRDGTBNWBTFKJ-UHFFFAOYSA-N 0.000 description 1
- 229910052590 monazite Inorganic materials 0.000 description 1
- 229910000480 nickel oxide Inorganic materials 0.000 description 1
- XNGIFLGASWRNHJ-UHFFFAOYSA-N o-dicarboxybenzene Natural products OC(=O)C1=CC=CC=C1C(O)=O XNGIFLGASWRNHJ-UHFFFAOYSA-N 0.000 description 1
- HMZGPNHSPWNGEP-UHFFFAOYSA-N octadecyl 2-methylprop-2-enoate Chemical compound CCCCCCCCCCCCCCCCCCOC(=O)C(C)=C HMZGPNHSPWNGEP-UHFFFAOYSA-N 0.000 description 1
- ZQPPMHVWECSIRJ-KTKRTIGZSA-N oleic acid Chemical compound CCCCCCCC\C=C/CCCCCCCC(O)=O ZQPPMHVWECSIRJ-KTKRTIGZSA-N 0.000 description 1
- 150000007524 organic acids Chemical class 0.000 description 1
- 229910000973 osmiridium Inorganic materials 0.000 description 1
- TWNQGVIAIRXVLR-UHFFFAOYSA-N oxo(oxoalumanyloxy)alumane Chemical compound O=[Al]O[Al]=O TWNQGVIAIRXVLR-UHFFFAOYSA-N 0.000 description 1
- BMMGVYCKOGBVEV-UHFFFAOYSA-N oxo(oxoceriooxy)cerium Chemical compound [Ce]=O.O=[Ce]=O BMMGVYCKOGBVEV-UHFFFAOYSA-N 0.000 description 1
- SIWVEOZUMHYXCS-UHFFFAOYSA-N oxo(oxoyttriooxy)yttrium Chemical compound O=[Y]O[Y]=O SIWVEOZUMHYXCS-UHFFFAOYSA-N 0.000 description 1
- PQQKPALAQIIWST-UHFFFAOYSA-N oxomolybdenum Chemical compound [Mo]=O PQQKPALAQIIWST-UHFFFAOYSA-N 0.000 description 1
- DUSYNUCUMASASA-UHFFFAOYSA-N oxygen(2-);vanadium(4+) Chemical compound [O-2].[O-2].[V+4] DUSYNUCUMASASA-UHFFFAOYSA-N 0.000 description 1
- 239000005022 packaging material Substances 0.000 description 1
- 238000012856 packing Methods 0.000 description 1
- FJKROLUGYXJWQN-UHFFFAOYSA-N papa-hydroxy-benzoic acid Natural products OC(=O)C1=CC=C(O)C=C1 FJKROLUGYXJWQN-UHFFFAOYSA-N 0.000 description 1
- 229910052954 pentlandite Inorganic materials 0.000 description 1
- 150000002989 phenols Chemical class 0.000 description 1
- 235000021317 phosphate Nutrition 0.000 description 1
- 150000003904 phospholipids Chemical class 0.000 description 1
- 150000003013 phosphoric acid derivatives Chemical class 0.000 description 1
- UXBZSSBXGPYSIL-UHFFFAOYSA-N phosphoric acid;yttrium(3+) Chemical compound [Y+3].OP(O)(O)=O UXBZSSBXGPYSIL-UHFFFAOYSA-N 0.000 description 1
- 150000003021 phthalic acid derivatives Chemical class 0.000 description 1
- 230000000704 physical effect Effects 0.000 description 1
- 230000010399 physical interaction Effects 0.000 description 1
- 229920001983 poloxamer Polymers 0.000 description 1
- 229920000885 poly(2-vinylpyridine) Polymers 0.000 description 1
- 229920000747 poly(lactic acid) Polymers 0.000 description 1
- 229920000768 polyamine Polymers 0.000 description 1
- 229920000647 polyepoxide Polymers 0.000 description 1
- 229920001223 polyethylene glycol Polymers 0.000 description 1
- 239000004626 polylactic acid Substances 0.000 description 1
- 229920005862 polyol Polymers 0.000 description 1
- 150000003077 polyols Chemical class 0.000 description 1
- 229920006380 polyphenylene oxide Polymers 0.000 description 1
- 229920001155 polypropylene Polymers 0.000 description 1
- 229920001451 polypropylene glycol Polymers 0.000 description 1
- 229920001343 polytetrafluoroethylene Polymers 0.000 description 1
- 239000004810 polytetrafluoroethylene Substances 0.000 description 1
- 235000011056 potassium acetate Nutrition 0.000 description 1
- WFIZEGIEIOHZCP-UHFFFAOYSA-M potassium formate Chemical compound [K+].[O-]C=O WFIZEGIEIOHZCP-UHFFFAOYSA-M 0.000 description 1
- 239000004323 potassium nitrate Substances 0.000 description 1
- 235000010333 potassium nitrate Nutrition 0.000 description 1
- 239000000843 powder Substances 0.000 description 1
- 239000002243 precursor Substances 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 102000004196 processed proteins & peptides Human genes 0.000 description 1
- 108090000765 processed proteins & peptides Proteins 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- UMJSCPRVCHMLSP-UHFFFAOYSA-N pyridine Natural products COC1=CC=CN=C1 UMJSCPRVCHMLSP-UHFFFAOYSA-N 0.000 description 1
- 239000011028 pyrite Substances 0.000 description 1
- 229910052952 pyrrhotite Inorganic materials 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 238000004064 recycling Methods 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 230000000246 remedial effect Effects 0.000 description 1
- SMQUZDBALVYZAC-UHFFFAOYSA-N salicylaldehyde Chemical compound OC1=CC=CC=C1C=O SMQUZDBALVYZAC-UHFFFAOYSA-N 0.000 description 1
- 229960004889 salicylic acid Drugs 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 239000002455 scale inhibitor Substances 0.000 description 1
- 239000013535 sea water Substances 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 229910021646 siderite Inorganic materials 0.000 description 1
- 229910052709 silver Inorganic materials 0.000 description 1
- 239000004332 silver Substances 0.000 description 1
- ADZWSOLPGZMUMY-UHFFFAOYSA-M silver bromide Chemical compound [Ag]Br ADZWSOLPGZMUMY-UHFFFAOYSA-M 0.000 description 1
- 239000002002 slurry Substances 0.000 description 1
- 239000001632 sodium acetate Substances 0.000 description 1
- 235000017281 sodium acetate Nutrition 0.000 description 1
- 229910000029 sodium carbonate Inorganic materials 0.000 description 1
- 239000011780 sodium chloride Substances 0.000 description 1
- 229940083575 sodium dodecyl sulfate Drugs 0.000 description 1
- HLBBKKJFGFRGMU-UHFFFAOYSA-M sodium formate Chemical compound [Na+].[O-]C=O HLBBKKJFGFRGMU-UHFFFAOYSA-M 0.000 description 1
- 235000019254 sodium formate Nutrition 0.000 description 1
- 235000019333 sodium laurylsulphate Nutrition 0.000 description 1
- 239000004317 sodium nitrate Substances 0.000 description 1
- 235000010344 sodium nitrate Nutrition 0.000 description 1
- 229960004025 sodium salicylate Drugs 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
- DAJSVUQLFFJUSX-UHFFFAOYSA-M sodium;dodecane-1-sulfonate Chemical compound [Na+].CCCCCCCCCCCCS([O-])(=O)=O DAJSVUQLFFJUSX-UHFFFAOYSA-M 0.000 description 1
- 239000012798 spherical particle Substances 0.000 description 1
- 230000003068 static effect Effects 0.000 description 1
- SKRWFPLZQAAQSU-UHFFFAOYSA-N stibanylidynetin;hydrate Chemical compound O.[Sn].[Sb] SKRWFPLZQAAQSU-UHFFFAOYSA-N 0.000 description 1
- 238000003860 storage Methods 0.000 description 1
- UBXAKNTVXQMEAG-UHFFFAOYSA-L strontium sulfate Inorganic materials [Sr+2].[O-]S([O-])(=O)=O UBXAKNTVXQMEAG-UHFFFAOYSA-L 0.000 description 1
- IHBMMJGTJFPEQY-UHFFFAOYSA-N sulfanylidene(sulfanylidenestibanylsulfanyl)stibane Chemical compound S=[Sb]S[Sb]=S IHBMMJGTJFPEQY-UHFFFAOYSA-N 0.000 description 1
- YPMOSINXXHVZIL-UHFFFAOYSA-N sulfanylideneantimony Chemical compound [Sb]=S YPMOSINXXHVZIL-UHFFFAOYSA-N 0.000 description 1
- WWNBZGLDODTKEM-UHFFFAOYSA-N sulfanylidenenickel Chemical compound [Ni]=S WWNBZGLDODTKEM-UHFFFAOYSA-N 0.000 description 1
- 150000004763 sulfides Chemical class 0.000 description 1
- 150000003871 sulfonates Chemical class 0.000 description 1
- 238000001308 synthesis method Methods 0.000 description 1
- 230000002194 synthesizing effect Effects 0.000 description 1
- XSOKHXFFCGXDJZ-UHFFFAOYSA-N telluride(2-) Chemical compound [Te-2] XSOKHXFFCGXDJZ-UHFFFAOYSA-N 0.000 description 1
- 229910052970 tennantite Inorganic materials 0.000 description 1
- 229910052969 tetrahedrite Inorganic materials 0.000 description 1
- YLQBMQCUIZJEEH-UHFFFAOYSA-N tetrahydrofuran Natural products C=1C=COC=1 YLQBMQCUIZJEEH-UHFFFAOYSA-N 0.000 description 1
- 239000002562 thickening agent Substances 0.000 description 1
- 125000000101 thioether group Chemical group 0.000 description 1
- ZCUFMDLYAMJYST-UHFFFAOYSA-N thorium dioxide Chemical compound O=[Th]=O ZCUFMDLYAMJYST-UHFFFAOYSA-N 0.000 description 1
- XSSPKPCFRBQLBU-UHFFFAOYSA-N thorium(iv) orthosilicate Chemical compound [Th+4].[O-][Si]([O-])([O-])[O-] XSSPKPCFRBQLBU-UHFFFAOYSA-N 0.000 description 1
- 229910052719 titanium Inorganic materials 0.000 description 1
- 239000004408 titanium dioxide Substances 0.000 description 1
- VZCYOOQTPOCHFL-UHFFFAOYSA-N trans-butenedioic acid Natural products OC(=O)C=CC(O)=O VZCYOOQTPOCHFL-UHFFFAOYSA-N 0.000 description 1
- GPRLSGONYQIRFK-MNYXATJNSA-N triton Chemical compound [3H+] GPRLSGONYQIRFK-MNYXATJNSA-N 0.000 description 1
- WFKWXMTUELFFGS-UHFFFAOYSA-N tungsten Chemical compound [W] WFKWXMTUELFFGS-UHFFFAOYSA-N 0.000 description 1
- 229910052721 tungsten Inorganic materials 0.000 description 1
- 239000010937 tungsten Substances 0.000 description 1
- 238000011144 upstream manufacturing Methods 0.000 description 1
- YIIYNAOHYJJBHT-UHFFFAOYSA-N uranium;dihydrate Chemical compound O.O.[U] YIIYNAOHYJJBHT-UHFFFAOYSA-N 0.000 description 1
- LSGOVYNHVSXFFJ-UHFFFAOYSA-N vanadate(3-) Chemical class [O-][V]([O-])([O-])=O LSGOVYNHVSXFFJ-UHFFFAOYSA-N 0.000 description 1
- 229910052821 vanadinite Inorganic materials 0.000 description 1
- 229910001935 vanadium oxide Inorganic materials 0.000 description 1
- MWOOGOJBHIARFG-UHFFFAOYSA-N vanillin Chemical compound COC1=CC(C=O)=CC=C1O MWOOGOJBHIARFG-UHFFFAOYSA-N 0.000 description 1
- FGQOOHJZONJGDT-UHFFFAOYSA-N vanillin Natural products COC1=CC(O)=CC(C=O)=C1 FGQOOHJZONJGDT-UHFFFAOYSA-N 0.000 description 1
- 235000012141 vanillin Nutrition 0.000 description 1
- ABDKAPXRBAPSQN-UHFFFAOYSA-N veratrole Chemical compound COC1=CC=CC=C1OC ABDKAPXRBAPSQN-UHFFFAOYSA-N 0.000 description 1
- 125000000391 vinyl group Chemical group [H]C([*])=C([H])[H] 0.000 description 1
- 229940102001 zinc bromide Drugs 0.000 description 1
- 239000011667 zinc carbonate Substances 0.000 description 1
- 235000004416 zinc carbonate Nutrition 0.000 description 1
- 229910052726 zirconium Inorganic materials 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/06—Arrangements for treating drilling fluids outside the borehole
-
- 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
- C09K8/92—Compositions for stimulating production by acting on the underground formation characterised by their form or by the form of their components, e.g. encapsulated material
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/01—Arrangements for handling drilling fluids or cuttings outside the borehole, e.g. mud boxes
-
- 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
- C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
- C09K8/46—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
- C09K8/467—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
- C09K8/48—Density increasing or weighting additives
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/516—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls characterised by their form or by the form of their components, e.g. encapsulated material
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
- C09K8/536—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning characterised by their form or by the form of their components, e.g. encapsulated material
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/70—Compositions for forming crevices or fractures characterised by their form or by the form of their components, e.g. foams
Definitions
- the present invention relates to precipitated particles and wellbore fluids and methods relating thereto.
- a variety of wellbore operations are performed, e.g., drilling operations, cementing operations, and stimulation operations.
- One physical property of the wellbore fluids used in conjunction with these wellbore operations is density.
- density For example during drilling operations, the density of a wellbore fluid must be carefully controlled so as to exert sufficient pressure to stabilize the walls of the wellbore, e.g. , to prevent blowouts, while simultaneously not exerting excess pressure that can cause damage to the surrounding subterranean formation.
- the density of spacer fluids and cementing operations must be carefully balanced so as to minimize or prevent mixing of other wellbore fluids on either side of the spacer fluid (e.g., a drilling fluid and a cementing fluid).
- weighting agent particles e.g. , specific gravity and particle size distribution
- weighting agent particles effect not only the density of the wellbore fluid, but also other wellbore fluid properties, like sag and viscosity.
- the ability to tailor the properties of the weighting agent to achieve desired wellbore fluid characteristics may allow for reduced cost by minimizing the need for other additives because the tailored weighting agent can achieve the desired wellbore fluid characteristics.
- the grinding process used to produce weighting agents provides little tailorability in terms of particle characteristics.
- the characteristics of the weighting agent particles e.g.
- particle shape and particle size distribution is primarily determined by the grinding procedure and the composition of the bulk mineral including any contaminants.
- sieves can be used to remove at least some of the larger or smaller particle sizes from the ground material .
- this provides limited ability to tailor the average particle size and particle size distribution of the weighting agent particles.
- the grind process offers no ability to tailor the shape and morphology of the weighting agent particles. Accordingly, methods that allow for the production of weighting agents with tailored characteristics and the methods that employ the resultant wellbore fluids would be of value to one in the art.
- the present invention relates to precipitated particles and wellbore fluids and methods relating thereto.
- One embodiment of the present invention provides for a wellbore drilling assembly that includes a pump in fluid communication with a wellbore via a feed pipe; and a wellbore fluid disposed in at least one selected from the group consisting of the pump, the feed pipe, the wellbore, and any combination thereof, wherein the wellbore fluid has a density of about 7 ppg to about 50 ppg and comprises a base fluid and a plurality of precipitated particles having a shape selected from the group consisting of ovular, substantially ovular, discus, platelet, flake, toroidal, dendritic, acicular, spiked with a substantially spherical or ovular shape, spiked with a discus or platelet shape, rod-like, fibrous, polygonal, faceted, star-shaped, and any hybrid thereof.
- a wellbore drilling assembly that includes a pump in fluid communication with a wellbore via a feed pipe; a drill string with drill bit attached to the distal end of the drill string ; and a wellbore fluid in contact with the drill bit, wherein the wellbore fluid has a density of about 7 ppg to about 50 ppg and comprises a base fluid and a plurality of precipitated particles having a shape selected from the group consisting of ovular, substantially ovular, discus, platelet, flake, toroidal, dendritic, acicular, spiked with a substantially spherical or ovular shape, spiked with a discus or platelet shape, rod-like, fibrous, polygonal, faceted, star- shaped, and any hybrid thereof.
- Yet another embodiment of the present invention provides for a wellbore drilling assembly that includes a pump capable of introducing a fluid into a wellbore via a feed pipe; a fluid processing unit capable of receiving the fluid from a wellbore via an interconnecting flow line; and a wellbore fluid disposed in at least one selected from the group consisting of the pump, the feed pipe, the wellbore, the interconnecting flow line, the fluid processing unit, and any combination thereof, wherein the wellbore fluid has a density of about 7 ppg to about 50 ppg and comprises a base fluid and a plurality of precipitated particles having a shape selected from the group consisting of ovular, substantially ovular, discus, platelet, flake, toroidal, dendritic, acicular, spiked with a substantially spherical or ovular shape, spiked with a discus or platelet shape, rod-like, fibrous, polygonal, faceted, star-shaped, and any hybrid thereof.
- Figures 1A-B illustrate examples of theoretical multi-modal diameter distributions for particles.
- Figure 2 illustrates an exemplary wellbore drilling assembly for use in conjunction with the mineral particles, related fluids, and related methods described herein.
- the present invention relates to precipitated particles and wellbore fluids and methods relating thereto.
- the present invention provides for, in some embodiments, precipitated particles that can be used in subterranean applications as unique weighting agents.
- Precipitated particle characteristics like shape and particle size distribution may, in some embodiments, be tailored during precipitation synthesis, for example, through pH and/or temperature.
- precipitation as a synthesis method may allow for unique shapes and narrow particle size distributions that can be exploited so as to achieve desired properties and capabilities in the corresponding wellbore fluids (e.g., density, viscosity, and sag control) .
- discus or platelet shaped precipitated particles may increase the viscosity of a wellbore fluid and settle in the wellbore fluid at a slower rate, thereby yielding a viscosified fluid with less sag .
- the ability to tailor the properties and capabilities of wellbore fluids may advantageously allow for the a reduction in other, potentially expensive and less environmentally-desirable, additives because the characteristics of the precipitated particles provide for the desired properties and capabilities of the wellbore fluid .
- the purity of the precipitated particles may be utilized to bring mined or ground weighting agents into an acceptable specification .
- some grades of mined barite contain high levels of sand and other particles.
- Precipitated particles described herein may be combined with such ground barite to decrease the overall abrasiveness and increase specific gravity of the weighting agent additive.
- ground minerals that are mined in some areas of the world may have higher levels of heavy metals like mercury or cadmium . The inclusion of the higher purity precipitated particles may dilute the contaminants to acceptable levels.
- the term “precipitated particles” encompasses single types of precipitated particles and combinations of more than one type of particle, including combinations of precipitated particles with non-precipitated particles. Distinctions between types of precipitated particles may, in some embodiments, be defined by at least one of composition, shape, median diameter, aspect ratio, diameter distribution, presence or absence of coating, coating composition, and the like, and any combination thereof. [0020] In some embodiments, the precipitated particles described herein may be formed by precipitation methods. The precipitation methods may advantageously yield precipitated particles that have desired characteristics (e.g. , size, shape, diameter distribution, median diameter, and the like) .
- Some embodiments of the present invention may involve precipitating particles from two or more salts in aqueous solutions so as to yield the precipitated particles described herein (or precursors to precipitated particles described herein, e.g. , particles that can be further calcined to yield precipitated particles described herein) .
- some embodiments of the present invention may involve precipitating manganese carbonate from manganese (II) salts in aqueous solutions with alkali metal carbonates so as to yield the precipitated manganese carbonate particles.
- Examples of other salts that may be used in producing precipitated particles may include salts (e.g., fluorides, chlorides, bromides, iodides, acetates, formates, citrates, sulfates, carbonates, hydroxides, phosphates, silicates, molybdates, tungstates, vanadates, titanates, chromates, and the like) of barium, bismuth, chromium, cobalt, copper, gold, iron, lead, nickel, strontium, tin, zinc, manganese, tungsten, aluminum, silver, cerium, magnesium, zirconium, titanium, calcium, antimony, lead, and the like, and any combination thereof.
- salts e.g., fluorides, chlorides, bromides, iodides, acetates, formates, citrates, sulfates, carbonates, hydroxides, phosphates, silicates, molybdates, tungstates, vana
- the concentration of salts used in the formation of precipitated particles may range from a lower limit of about 1 mM, 10 m M, or 50 m M to an upper limit of about 5 M, 1 M, or 100 m M, and wherein the concentration may range from any lower limit to any upper limit and encompasses any subset therebetween.
- the precipitated particles described herein that are formed by precipitation methods may comprise at least one of Agl, AgCI, AgBr, AgCuS, AgS, Ag 2 S, Al 2 0 3 , AsSb, AuTe 2 , BaC0 3 , BaS0 4 , BaCr0 4 , BaO, BeO, BiOCI, (BiO) 2 C0 3 , Bi0 3 , Bi 2 S 3 , Bi 2 0 3 , CaO, Ca F 2 , CaW0 4 , CaC0 3 , (Ca, Mg)C0 3 , CdS, CdTe, Ce 2 0 3 , CoAsS, Cr 2 0 3 , CuO, Cu 2 0, CuS, Cu 2 S, CuS 2 , CugS 5 , CuFeS 2 , Cu 5 FeS 4 , CuS ⁇ Co 2 S 3 , Fe 2+ Al 2 0 4 , Fe 2 Si0 4 , FeW0 4 ,
- combination of more than one salt may be used to form precipitated particles with two or more of the foregoing precipitates in substantially homogeneous domain.
- strontium and barium salts may be utilized in forming precipitated particles that comprise (Ba,Sr)S0 4 or (Ba,Sr)C0 3 .
- barium salts may be used in forming precipitated particles that comprise Ba(S0 4 ,Cr0 4 ).
- Examples of other substantially homogeneous domains may include, but are not limited to, suitable mixtures of barium, strontium, calcium, zinc, iron, cobalt, manganese, lead, tin, and the like, and any combination thereof in the form of sulfates, carbonates, hydroxide, oxides, sulfides, chromates and the like, and any combination thereof.
- Some embodiments may involve forming precipitated particles with discrete domains that comprise at least one of the foregoing precipitates.
- a calcium carbonate particle may be formed by precipitation and then barium salts added so as to precipitate barium carbonate on at least a portion of the surface of the calcium carbonate precipitated particle.
- a higher specific gravity composition like those comprising bismuth may be precipitated and then a different composition precipitated thereon.
- Precipitating a second composition on a first composition may allow for the first composition to be formed with a desired shape and the second composition to increase the specific gravity of the particle, which may allow for a desired higher specific gravity particle with a desired shape that may be difficult to achieve otherwise.
- the higher specific gravity particle may be the first composition and the second composition precipitated thereon may enable linking of the particles or reduce the abrasiveness of the particles (described further herein).
- the particles produced by precipitation may be calcined to yield precipitated particles described herein. Calcining may, inter alia, increase the mechanical properties (e.g. , crush strength) of the precipitated particles, yield a corresponding oxide (e.g., manganese carbonate to manganese oxide, calcium carbonate to calcium oxide, bismuth carbonate to bismuth oxycarbonate or bismuth oxide, zirconium hydroxide to zirconium oxide, or magnesium hydroxide to magnesium oxide), or any combination thereof.
- a corresponding oxide e.g., manganese carbonate to manganese oxide, calcium carbonate to calcium oxide, bismuth carbonate to bismuth oxycarbonate or bismuth oxide, zirconium hydroxide to zirconium oxide, or magnesium hydroxide to magnesium oxide
- the precipitated particles described herein may be shaped as spherical, ovular, substantially spherical, substantially ovular, discus, platelet, flake, toroidal (such as donut-shaped), dendritic, acicular, spiked with a substantially spherical or ovular shape (such as a sea urchin), spiked with a discus or platelet shape, rod-like, fibrous (such as high- aspect ratio shapes), polygonal (such as cubic or pyramidal), faceted (such as the shape of crystals), star or floral shaped (such as a tripod or tetrapod where rods or the like extend from a central point), or any hybrid thereof (e.g., a dumbbell-shape).
- spherical, ovular, substantially spherical, and substantially ovular-shaped precipitated particles may be useful in producing wellbore fluids that are less abrasive to wellbore tools and/or decrease viscosity as compared to ground particles.
- platelet, flake, acicular, spiked with a discus or platelet shape, rod-like, and fibrous-shaped precipitated particles may be useful in producing wellbore fluids with less sag and/or greater viscosity as compared to ground particles.
- the terms “median diameter” and “diameter distribution” refers to a weight median diameter and a weight diameter distribution, respectively, wherein the diameter is based on the largest dimension of the particles. For example, rod-like particles would have diameter distributions and the like based on the length of the rod-like particles. As used herein, the term “median diameter” refers to a diameter distribution wherein 50% of the particles are smaller than a given value.
- the precipitated particles described herein may have a median diameter ranging from a lower limit of about 5 nm, 10 nm, 20 nm, 50 nm, 100 nm, 250 nm, 500 nm, or 1 micron to an upper limit of about 100 microns, 50 microns, 25 microns, 10 microns, 5 microns, 1 micron, or 750 nm, and wherein the median diameter may range from any lower limit to any upper limit and encompasses any subset therebetween .
- precipitation methods may be used to yield larger sizes of particles that are millimeters or larger in size. For example, precipitated particles having a median diameter of about 1- 10 mm may be used as proppants or lost circulation materials.
- the precipitated particles may be ground to achieve a desired size and/or shape.
- Methods that involve precipitation and then grinding may advantageously allow for production of higher purity precipitated particles as compared to particles produced by grinding bulk minerals. Further, such methods may allow for reduced cost while maintaining high purity as compared to some precipitation methods with steps to control particle size.
- larger precipitated particles may be directly added to a mined mineral and undergo the same grinding process such that the ground product may have a higher purity than the mineral alone.
- large particles of barium sulfate may formed by precipitation and added to mined barite with high levels of contaminants (e.g. , greater than 15% sand) such that the ground product is higher purity, which yields a less abrasive, higher specific gravity weighting agent that is of greater value in the industry.
- the precipitated particles may have a narrow diameter distribution . That is, the diameter distribution (or at least one mode of a multimodal diameter distribution) may have a standard deviation of about 2% or less of the peak diameter for the given mode (e.g., about 0.1% to about 2% or any subset therebetween) . In some embodiments, it is believed that precipitation methods may be advantageously employed to achieve narrow diameter distributions of precipitated particles described herein .
- the conditions under which the precipitated particles are formed may be manipulated so as to assist in controlling or directing the characteristics of the precipitated particles (e.g., shape, median diameter, diameter distribution, narrow diameter distribution, density, hardness, and the like) .
- characteristics of the precipitated particles e.g., shape, median diameter, diameter distribution, narrow diameter distribution, density, hardness, and the like
- conditions that can be manipulated may include, but are not limited to, pH, temperature, chemical composition of morphology modifiers, concentration of morphology modifiers, concentration of the salts used in the production of the precipitated particles, and the like, and any combination thereof. For example, increasing the pH and/or temperature may increase the median diameter of the precipitated particles.
- forming precipitated particles may be at a pH ranging from a lower limit of about 2, 3, 4, 5, 7, or 8 to an upper limit of about 12, 11, 10, 9, 8, 7, or 6, and wherein the pH may range from any lower limit to any upper limit and encompasses any subset therebetween .
- forming precipitated particles may be at a temperature ranging from a lower limit of about 10°C, 20°C, 30°C, 40°C, or 50°C to an upper limit of about 95°C, 90°C, 80°C, 70°C, or 60°C, and wherein the temperature may range from any lower limit to any upper limit and encompasses any subset therebetween.
- morphology modifiers refers to chemicals that are used during the formation of precipitated particles that effect the characteristics of the precipitated particles.
- examples of morphology modifiers may include, but are not limited to, polymers, surfactants, electrolytes, hydrogen peroxide, silicates and other similar inorganic materials, aqueous- miscible organic liquids, and the like, and any combination thereof.
- morphology modifiers may direct the formation of the precipitated particles in one of at least two ways.
- the morphology modifiers may form structures within the precipitation fluid that direct the growth of the precipitated particle.
- block copolymers may form micelles in aqueous solutions (e.g. , spherical micelles, rod-like micelles, worm-like micelles, and the like depending on, inter alia, concentration and pH) that direct the growth of the precipitated particles based on the size and shape of the micelles.
- the morphology modifiers may interact directly with various portions of the surface of the precipitated particles so as to decrease or enhance growth of that portion of the surface.
- both of the foregoing factors may be involved .
- the shape of the resultant precipitated particles can be drastically altered, e.g. , barium sulfate precipitated particles may be dumbbell-shaped when utilizing PEO-co-PEI-COOH, fibrous or needle-like with PEO-co-PEI-P0 3 H 2 , or floral- shaped with PEO-co-PEI-S0 3 H as compared to a faceted structure without the polymer.
- polymers that may be useful as morphology modifiers may, in some embodiments, include, but are not limited to, peptides, PEO-co-PEI-SOsH, PEO-co-PEI-COOH, PEO-co-PEI-P0 3 H 2 , PEO-co-polypropylene oxide (PPO), PPO-co-PEO-co-PPO, PEO-co-polyethylene (PE), PPO-co- poly(methacrylic acid) (PMAA), PEO-co-poly(2-vinylpyridine) (P2VP), P2VP-co- polyacrylic acid (PAA), PM MA-co-PAA, polystyrene sulfonate (PSS), PEO, PPO, PEI, PEI-SO3H, PEI-COOH, PEI- PO3H2, PMAA, and the like, salts thereof where appropriate, any derivative thereof, and any combination thereof.
- PEO-co-PEI-SOsH PEO-co-PE
- monomers selected from the group comprising : acrylic acid, itaconic acid, maleic acid or anhydride, hydroxypropyl acrylate vinylsulphonic acid, acrylamido 2- propane s
- Examples of commercially available polymers may include Pluronic® surfactants (polyethylene oxide-polypropylene oxide-polyethylene oxide triblock polymers, available from BASF), Tetronic® surfactants (tetra-functional block copolymers based on ethylene oxide and propylene oxide, available from BASF), and the like, and any combination thereof.
- Pluronic® surfactants polyethylene oxide-polypropylene oxide-polyethylene oxide triblock polymers, available from BASF
- Tetronic® surfactants tetra-functional block copolymers based on ethylene oxide and propylene oxide, available from BASF
- the resultant particles may be at least partially coated with the polymers.
- molecular weight of the polymer may effect the characteristics of the resultant precipitated particle.
- PSS polymers used in the synthesis of precipitated particles e.g., carbonate particles
- the molecular weight of polymers used as morphology modifiers in the formation of precipitated particles may range from a lower limit of about 10,000 g/mol, 25,000 g/mol, 100,000 g/mol, or 250,000 g/mol to an upper limit of about 2,000,000 g/mol, 1,000,000 g/mol, 500,000 g/mol, or 250,000 g/mol, and wherein the molecular weight may range from any lower limit to any upper limit and encompasses any subset therebetween .
- the concentration of polymers used as morphology modifiers in the formation of precipitated particles may range from a lower limit of about 0.1 g/L, 1 g/L, or 5 g/L to an upper limit of about 100 g/L, 25 g/L, 10 g/L, or 5 g/L, and wherein the concentration may range from any lower limit to any upper limit and encompasses any subset therebetween .
- surfactants examples include Brij® surfactants (ethoxylated fatty alcohols, available from Sigma- Aldrich), Triton® surfactants (ethoxylated fatty alkylphenols, available from Sigma-Aldrich), and the like, and any combination thereof.
- Brij® surfactants ethoxylated fatty alcohols, available from Sigma- Aldrich
- Triton® surfactants ethoxylated fatty alkylphenols, available from Sigma-Aldrich
- the concentration of surfactants used as morphology modifiers in the formation of precipitated particles may range from a lower limit of about 0.1 g/L, 1 g/L, or 5 g/L to an upper limit of about 100 g/L, 25 g/L, 10 g/L, or 5 g/L, and wherein the concentration may range from any lower limit to any upper limit and encompasses any subset therebetween .
- aqueous-miscible organic liquids that may be useful as morphology modifiers may, in some embodiments, include, but are not limited to, acetone, dimethyl formamide, methanol, ethanol, n-propanol, isopropanol, n-butanol, sec-butanol, isobutanol, t-butanol, glycerol, pyridine, tetrahydrofuran, and the like.
- the concentration of aqueous-miscible organic liquids used as morphology modifiers in the formation of precipitated particles may range from a lower limit of about 1%, 10%, or 25% by volume of the precipitation fluid to an upper limit of about 98%, 75%, or 50% by volume of the precipitation fluid, and wherein the concentration may range from any lower limit to any upper limit and encompasses any subset therebetween .
- multiple morphology modifiers may be manipulated to achieve precipitated particles with desired characteristics.
- hydrogen peroxide concentration and pH may be adjusted to change the surface of precipitated particles, e.g., with respect to calcium carbonate precipitated particles, higher pH values (e.g. , about 11) and higher hydrogen peroxide concentrations may yield calcium carbonated precipitated particles with smaller faceted protrusions (or spikes) on the surface as compared to a lower pH (e.g. , about 9) and lower hydrogen peroxide concentrations that may yield larger, smoother facets along the surface of the precipitated particle.
- the precipitation time may be adjusted to allow for particle fusion to yield dumbbell or peanut-shaped precipitated particles that depending on the pH and hydrogen peroxide concentration may have large faceted surfaces or small faceted protrusions.
- wellbore additives and/or wellbore fluids may comprise the precipitated particles described herein. Such wellbore additives and/or wellbore fluids may be used in conjunction with a plurality of wellbore operations.
- wellbore operation refers to any treatment or operation suitable for use in conjunction with a wellbore and/or subterranean formation, e.g. , drilling operations, lost circulation operations, fracturing operations, cementing operations, completion operations, and the like.
- the wellbore additives and/or the wellbore fluids may comprise the precipitated particles described herein having a multimodal diameter distribution (e.g. , bimodal, trimodal, and so on).
- the wellbore additives and/or the wellbore fluids may comprise the precipitated particles described herein having a multimodal diameter distribution such that at least one mode has an median diameter (or peak diameter) ranging from a lower limit of about 5 nm, 10 nm, 20 nm, 50 nm, 100 nm, 250 nm, 500 nm, or 1 micron to an upper limit of about 50 microns, 10 microns, 5 microns, 1 micron, or 500 nm and at least one mode has an median diameter ranging from a lower limit of about 10 microns, 25 microns, 50 microns, or 100 microns to an upper limit of about 5000 microns, 2500 microns, 1000 microns, 500 microns, 100 micron
- Figures 1A-B illustrate theoretical multimodal diameter distributions for use in wellbore fluids.
- Figure 1A illustrates a bimodal diameter distribution with a first mode median diameter of about 1 micron and a second mode median diameter of about 25 microns.
- Figure IB illustrates a trimodal diameter distribution with a first mode median diameter of about 5 microns, a second mode median diameter of about 50 microns, and a third mode median diameter of about 90 microns.
- the mode(s) of a diameter distribution may independently be considered to have a narrow diameter distribution. That is, at least one mode of a diameter distribution (including monomodal) may have a standard deviation of about 2% or less of the peak diameter for the given mode (e.g. , about 0.1% to about 2% or any subset therebetween). In some embodiments, it is believed that precipitation methods may be advantageously employed to achieve narrow diameter distributions of precipitated particles described herein.
- the precipitated particles described herein may be added to a wellbore fluid to achieve a desired density of the wellbore fluid .
- the wellbore fluids described herein may have a density between a lower limit of about 7 pounds per gallon ("ppg"), 9 ppg, 12 ppg, 15 ppg, or 22 ppg to an upper limit of about 50 ppg, 40 ppg, 30 ppg, 22 ppg, 20 ppg, or 17 ppg, and wherein the density of the wellbore fluid may range from any lower limit to any upper limit and encompasses any subset therebetween.
- ppg pounds per gallon
- the ability to achieve a desired density of the wellbore fluid while maintaining a fluid that can be pumped may depend on, inter alia, the composition and specific gravity of the precipitated particles, the shape of the precipitated particles, the concentration of the precipitated particles, and the like, and any combination thereof.
- wellbore fluids having a density of about 25 ppg or higher may be achieved with precipitated particles having a specific gravity of about 7 or greater (e.g. , Bi0 3 and/or Bi 2 0 3 ) and having a shape of spherical, substantially spherical, ovular, substantially ovular, or a hybrid thereof so as to allow for the fluid to be pumpable.
- wellbore fluids having a density of about 30 ppg or less may be achieved with precipitated particles having a specific gravity of about 7 or greater and having a larger variety of shapes, including discus.
- a mixture of two or more types of precipitated particles (or a mixture of precipitated and non-precipitated particles) described herein having a multiparticle specific gravity may be added to a wellbore fluid for a desired density.
- multiparticle specific gravity refers to the calculated specific gravity from Formula I.
- vol% is the volume percent of particle relative to the total volume of the particles used as weighting agent, sg is the specific gravity of the particle, A is the first particle, B is the second particle, and n is the n th particle
- the wellbore additives and/or the wellbore fluids may comprise a mixture of precipitated particles described herein having a multiparticle specific gravity ranging from a lower limit of about 3, 4, 4.5, 5, or 5.5 to an upper limit of about 20, 15, 10, 9, 8, or 7, and wherein the multiparticle specific gravity may range from any lower limit to any upper limit and encompasses any subset therebetween .
- specific gravity refers to the multiparticle specific gravity.
- the mixture of precipitated particles may comprise at least one precipitated particle and at least one non-precipitated particle (e.g.
- non-precipitated particles may include, but are not limited to, particles having a specific gravity greater than about 2.6 comprising at least one of BaS0 4 , CaC0 3 , (Ca, Mg)C0 3 , FeC0 3 , Fe 2 0 3 , a-Fe 2 0 3 , a-FeO(OH), Fe 3 0 4 , FeTi0 3 , (Fe, Mg)Si0 4 , SrS0 4 , MnO, Mn0 2 , Mn 2 0 3 , Mn 3 0 4 , Mn 2 0 7 , MnO(OH), (Mn 2+ ,Mn 3+ ) 2 0 4 , barite, calcium carbonate, dolomite, hematite, siderite, magnetite, manganese dioxide, manganese (IV) oxide, manganese oxide, manganese tetraoxide, manganese (II
- the precipitated particles may be present in the wellbore fluid in an amount sufficient for a particular application.
- the precipitated particles may be present in a wellbore fluid in an amount up to about 70% by volume of the wellbore fluid (v%) ⁇ e.g., about 5 v%, about 15 v%, about 20 v%, about 25 v%, about 30 v%, about 35 v%, about 40 v%, about 45 v%, about 50 v%, about 55 v%, about 60 v%, about 65 v%, etc.).
- the precipitated particles may be present in the wellbore fluid in an amount of 10 v% to about 40 v%.
- the precipitated particles described herein may have tailored characteristics that can be exploited to achieve desired properties and/or capabilities in a wellbore fluid beyond density, e.g. , sag control .
- Particles e.g. , weighting agents, proppants, and cement particles
- the term "sag” refers to an inhomogeneity in density of a fluid in a wellbore, e.g. , along the length of a wellbore and/or the diameter of a deviated wellbores.
- sag can cause to portions of the wellbore fluid to be at an insufficient density to stabilize the wellbore and other portions of the wellbore fluid to have increased density. Unstabilized portions of the wellbore can lead to wellbore collapse and/or pressure buildups that cause blowouts. Increased density can cause wellbore damage (e.g., undesired fracturing of the wellbore), which may show up as pressure increases or decreases when changing from static to flow conditions of the fluid which can cause higher than desired pressures downhole.
- wellbore damage e.g., undesired fracturing of the wellbore
- the precipitated particles described herein may be sized, shaped, or otherwise treated ⁇ e.g. , coated) so as to mitigate sag in wellbore fluids.
- the size may, inter alia, provide for the formation of a stable suspension that exhibit low viscosity under shear.
- the specific gravity of the precipitated particles may further allow for such precipitated particles to provide for a desired density of the wellbore fluid while mitigating sag of these precipitated particles or other particles therein.
- Sag control can be measured by analyzing density changes in an undisturbed sample of wellbore fluid over time at a typical wellbore temperature ⁇ e.g. , about 300°F) and an elevated pressure ⁇ e.g. , about 5,000 psi to about 10,000 psi).
- the precipitated particles described herein that provide effective sag control may, in some embodiments, yield wellbore fluids having a change in density of less than about 1 ppg ⁇ e.g., about 0.5 ppg change or less including no change in density) when comparing a fluid's original density to the fluid's density at the bottom of a sample having been undisturbed for a given amount of time.
- the precipitated particles described herein may provide sag control ⁇ i.e. , a density change of less than about 1 ppg) over a time ranging from a lower limit of about 10 hours, 24 hours, 36 hours, or 48 hours to an upper limit of about 120 hours, 96 hours, 72 hours, or 48 hours, and wherein the sag control timeframe of the wellbore fluid may range from any lower limit to any upper limit and encompasses any subset therebetween.
- the properties of the precipitated particles described herein may be tailored to achieve sag control .
- Properties of the precipitated particles that can be tailored to achieve sag control may include, but are not limited to, size ⁇ e.g. , median diameter of about 2 microns or less or at least one mode of a multimodal distribution having such a peak diameter), shape ⁇ e.g., particle shapes with lower sphericity like discus, platelet, flake, acicular, spiked with a substantially spherical or ovular shape, spiked with a discus or platelet shape, fibrous, toroidal, and the like), coatings, linking (described further herein), and the like, and any combination thereof.
- the size and shape of each of the precipitated particles may be tailored so as to minimize separation of the precipitated particles, which may lead to a wellbore fluid with a striated density profile.
- a first precipitated particle with a discus or platelet shape may impede the settling of a second precipitated particle that has a high settling or migration rate (e.g., a higher specific gravity, spherical particle).
- the properties of the precipitated particles described herein may be tailored to mitigate the abrasion of wellbore tools (e.g. , pumps, drill bits, drill string, and a casing) as compared to comparable API grade barite (i.e., a comparable wellbore fluid having the same density and/or sag as the wellbore fluid comprising the precipitated particles), which may prolong the life of the wellbore tools.
- wellbore tools encompasses tools suitable for use in conjunction with wellbore operations, including tools that are used outside of the wellbore, e.g., pumps, shakers, and the like.
- Abrasion can be measured by the ASTM G75-07 and is reported as a Miller Number or a SAR Number.
- Suitable precipitated particles can be those with properties tailored to mitigate abrasion, which may include, but are not limited to, hardness (e.g. , a Mohs hardness of less than about 5), size (e.g. , median diameter less than about 400 nm or mode of a multimodal distribution having an peak diameter less than about 400 nm), shape (e.g. , particle shapes with higher sphericity like spherical, substantially spherical, ovular, substantially ovular, and the like), coatings (e.g., thicker and/or elastic coatings that minimize physical interactions between the mineral portion of the precipitated particle and the wellbore tool), and the like, and any combination thereof.
- the wellbore fluids may comprise substantially spherical awaruite particles with a median diameter less than about 400 nm and manganese carbonate particles, which have a Mohs hardness less than about 5.
- At least some of the precipitated particles described herein may, in some embodiments, be capable of being linked by linking agents. Linking of precipitated particles may allow for increasing the viscosity of the wellbore fluid or forming a solid mass described further herein.
- the composition of the precipitated particles described herein may determine if the precipitated particles are suitable for being linked and to what degree they can be linked.
- linkable precipitated particles may include, but are not limited to, those that comprise at least one of Al 2 0 3 , BaC0 3 , BaO, BeO, (BiO) 2 C0 3 , Bi0 3 , Bi 2 0 3 , CaO, CaC0 3 , (Ca,Mg)C0 3 , CdS, CdTe, Ce 2 0 3 , Cr 2 0 3 , CuO, Cu 2 0, Fe 2+ Al 2 0 4 , Fe 2 Si0 4 , FeC0 3 , Fe 2 0 3 , a-Fe 2 0 3 , a-FeO(OH), Fe 3 0 4 , FeTi0 3 , MgO, MnC0 3 , MnO, Mn0 2 , Mn 2 0 3 , Mn 3 0 4 , Mn 2 0 7 , MnO(OH), CaMo0 4 , MoS 2 , Mo0 2 , Mo0 3 , Nb0
- linking agents suitable for use in conjunction with the precipitated particles may, in some embodiments, include, but are not limited to, eugenol, guaiacol, methyl guaiacol, salicyladehyde, salicyladimine, salicylic acid, sodium salicylate, acetyl salicylic acid, methyl salicylic acid, methyl acetylsalicylic acid, anthranilic acid, acetyl anthranilic acid, vanillin, derivatized 1,2-dihydroxybenzene (catechol), derivatized or unsubstituted phthalic acid, ortho-phenylenediamine, ortho-aminophenol, ortho-hydroxyphenylacetic acid, alkylsilanes, esters, ethers, and the like, and any combination thereof.
- polymers of the foregoing examples, or suitable derivatives thereof may be used as linking agents.
- vinyl derivatives of the foregoing examples may be used in synthesizing a polymer or copolymer suitable for use as a linking agents.
- carboxylated derivates of the foregoing examples may be used in derivatizing a polyamine to yield suitable linking agents.
- Additional examples may include, but are not limited to, compounds (including polymers and lower molecular weight molecules) having at least two silane moieties, ester moieties, ether moieties, sulfide moieties, amine moieties, and the like, and any combination thereof.
- Viscosity increases from linking with linking agents may, in some embodiments, yield wellbore fluids that remain pumpable, wellbore fluids that are non-pumpable, or hardened masses.
- One skilled in the art with the benefit of this disclosure should understand that the extent of the viscosity increase may depend on, inter alia, the composition of the precipitated particles described herein, the composition of the linking agents, the relative concentration of the precipitated particles and the linking agents, intended use, additional components in the wellbore fluid, and any combination thereof.
- the precipitated particles described herein may advantageously have a higher unconfined compressive strength (e.g. , about 1200 psi or greater) that allow for load-bearing applications (e.g. , proppant applications).
- the precipitated particles described herein may advantageously have a moderate to high unconfined compressive strength (e.g. , about 500 psi or greater) that allow for implementation in applications like cements, wellbore strengthening additives, and gravel packs.
- the unconfined compressive strength of a precipitated particle may depend on, inter alia, the composition of the precipitated particle, the shape of the precipitated particle, additional processing steps in producing the precipitated particle (e.g. , calcining after precipitation), and the like, and any combination thereof.
- such precipitated particles may comprise at least one of Al 2 0 3 , CaF 2 , CaW0 4 , CaC0 3 , (Ca,Mg)C0 3 , CuO, Cu 2 0, CuS, Cu 2 S, CuS 2 , Cu 9 S 5 , CuFeS 2 , Cu 5 FeS 4 , CuS ⁇ Co 2 S 3 , Fe 2+ Al 2 0 4 , Fe 2 Si0 4 , FeW0 4 , FeS, FeS 2 , FeC0 3 , Fe 2 0 3 , a-Fe 2 0 3 , a-FeO(OH), Fe 3 0 4 , FeTi0 3 , MnC0 3 , Mn 2 S, MnW0 4 , MnO, Mn0 2 , Mn 2 0 3 , Mn 3 0 4 , Mn 2 0 7 ,
- At least some of the precipitated particles described herein may, in some embodiments, be at least partially degradable.
- the term "degradable” refers to a material being capable of reduced in size by heterogeneous degradation (or bulk erosion) and homogeneous degradation (or surface erosion), and any stage of degradation in between these two. This degradation can be a result of, inter alia, a chemical or thermal reaction, for example, dissolution by an acidic fluid.
- the composition of the precipitated particles described herein may determine if the precipitated particles are degradable and to what extent they are degradable.
- degradable precipitated particles may comprise at least one of BaC0 3 , (BiO) 2 C0 3 , CaW0 4 , CaC0 3 , CuO, FeC0 3 , PbC0 3 , (PbCI) 2 C0 3 , SrC0 3 , ZnC0 3 , and any combination thereof.
- Degradation of the precipitated described herein may advantageously be used in a plurality of wellbore operations, e.g., cleanup operations (e.g. , in removing a filter cake or plug from a lost circulation operation) and cementing operations (e.g. , in enhancing the permeability of a cement plug to allow for fluid to flow therethrough while still providing structural strength). Additionally, degradation may be advantageous in reducing the viscosity of a fluid by degrading precipitated particles that contribute to the viscosity (e.g. , by shape and/or by linking).
- Examples of degradation agents that may be useful in at least partially degrading precipitated particles described herein may, in some embodiments, include, but are not limited to, acid sources (e.g. , inorganic acids, organic acid, and polymers that degrade into acids like polylactic acid), alkaline sources (e.g. , bases), and oxidizers (e.g. , peroxide compounds, permanganate compounds, and hexavalent chromium compounds).
- acid sources e.g. , inorganic acids, organic acid, and polymers that degrade into acids like polylactic acid
- alkaline sources e.g. , bases
- oxidizers e.g. , peroxide compounds, permanganate compounds, and hexavalent chromium compounds.
- the precipitated particles described herein may be chosen so as to degrade over a desired amount of time, which may be dependent on, inter alia, particle size, particle shape, wellbore temperature, and precipitated particle composition.
- calcium carbonate rather than lead carbonate may be utilized, in some embodiments, when for faster degradation.
- manganese carbonate may, in some embodiments, be chosen for slower degradation in colder wellbore environments and faster degradation in hotter wellbore environments.
- the precipitated particles described herein may have a coating on at least a portion of the surface of the precipitated particles.
- coating does not imply any particular degree of coating on the particle.
- coat does not imply 100% coverage by the coating on the particle.
- a coating may, in some embodiments, be covalently and/or noncovalently associate with the precipitated particles described herein.
- a coating suitable for use in conjunction with the precipitated particles described herein may include, but are not limited to, polymers, surfactants, and any combination thereof. Coatings may, in some embodiments, assist in the suspension of the precipitated particles and/or the compatibility of the precipitated particles with a wellbore fluid and/or wellbore operation. For example, a coating like an alkyl amine may, in some embodiments, associate with the surface of the precipitated particles so as to render the precipitated particle more hydrophobic, which may enhance the suspendability of the precipitated particles in oil-based fluids. [0072] In some embodiments, precipitated particles may be coated after addition to the wellbore fluid.
- a coating may be applied during production of the precipitated particles described herein.
- grinding production methods may, in some embodiments, be conducted in the presence of polymers, surfactants, or the like suitable for use as a coating .
- precipitation production methods may be conducted in the presence of polymers, surfactants, or the like suitable for use as a coating .
- polymers, surfactants, or the like in a production method of the precipitated particles described herein should be chosen so as not to significantly impact the production in a negative manner.
- Polymers suitable for use in conjunction with the coated precipitated particles described herein may, in some embodiments, have a molecular weight ranging from a lower limit of about 10,000 g/mol, 25,000 g/mol, 100,000 g/mol, or 250,000 g/mol to an upper limit of about 2,000,000 g/mol, 1,000,000 g/mol, 500,000 g/mol, or 250,000 g/mol, and wherein the molecular weight may range from any lower limit to any upper limit and encompasses any subset therebetween.
- coating may comprise the polymers list herein that may be useful as morphology modifiers.
- the polymers may be used as morphology modifiers any yield coated precipitated particles.
- the precipitated particles may be formed and then polymers suitable for use as morphology modifiers may be used as coatings.
- coatings may comprise consolidating agents that generally comprise any compound that is capable of minimizing particulate migration once placed, which may be suitable for methods and compositions relating to proppant packs, gravel packs, and the like.
- Suitable consolidating agents may include, but are not limited to, non-aqueous tackifying agents, aqueous tackifying agents, emulsified tackifying agents, silyl-modified polyamide compounds, resins, crosslinkable aqueous polymer compositions, polymerizable organic monomer compositions, consolidating agent emulsions, zeta-potential modifying aggregating compositions, silicon-based resins, and binders. Combinations and/or derivatives of these also may be suitable.
- Nonlimiting examples of suitable non-aqueous tackifying agents may be found in U.S. Patent Nos. 7,392,847, 7,350,579, 5,853,048; 5,839,510; and 5,833,000, the entire disclosures of which are herein incorporated by reference.
- suitable aqueous tackifying agents may be found in U.S. Patent Nos. 8,076,271, 7, 131,491, 5,249,627 and 4,670,501, the entire disclosures of which are herein incorporated by reference.
- Nonlimiting examples of suitable crosslinkable aqueous polymer compositions may be found in U .S. Patent Application Publication No. 2010/0160187 and U .S. Patent No.
- Nonlimiting examples of suitable silyl-modified polyamide compounds may be found in U.S. Patent No. 6,439,309 entitled the entire disclosure of which is herein incorporated by reference.
- suitable resins may be found in U .S. Patent Nos. 7,673,686; 7, 153,575; 6,677,426; 6,582,819; 6,311,773; and 4,585,064 as well as U.S. Patent Application Publication No. 2008/0006405 and U.S. Patent No. 8,261,833, the entire disclosures of which are herein incorporated by reference.
- Nonlimiting examples of suitable polymerizable organic monomer compositions may be found in U.S.
- Patent No. 7,819,192 the entire disclosure of which is herein incorporated by reference.
- suitable consolidating agent emulsions may be found in U .S. Patent Application Publication No. 2007/0289781 the entire disclosure of which is herein incorporated by reference.
- suitable zeta-potential modifying aggregating compositions may be found in U .S. Patent Nos. 7,956,017 and 7,392,847, the entire disclosures of which are herein incorporated by reference.
- suitable silicon-based resins may be found in Application Publication Nos. 2011/0098394, 2010/0179281, and U.S. Patent Nos.
- the wellbore additives may comprise the precipitated particles described herein and optionally further comprise other particles and/or additional components suitable for use in a specific wellbore operation (e.g., proppants and cement particles as described further herein).
- Wellbore additives may, in some embodiments, be dry powder or gravel, a liquid with a high concentration of the precipitated particles described herein (e.g. , a slurry), and the like.
- the ratio of the various particles may depend on, inter alia, the desired properties and/or characteristics of the wellbore fluid.
- Distinctions between types of precipitated particles may, in some embodiments, be defined by at least one of mineral composition, production method, median diameter, diameter distribution, presence or absence of coating, coating composition, and the like, and any combination thereof.
- achieving homogeneous mixtures of dry wellbore additives may be aided by inclusion of a dry lubricant to facilitate homogeneous mixing and flowability.
- dry lubricant may, in some embodiments, include, but are not limited to, molybdenum disulfide, graphite, boron nitride, tungsten disulfide, polytetrafluoroethylene particles, bismuth sulfide, bismuth oxychloride, and the like, and any combination thereof.
- a dry lubricant may advantageously have a specific gravity greater than about 2.6 (e.g. , molybdenum disulfide, tungsten disulfide, bismuth sulfide, and bismuth oxychloride) so as contribute to the density of the resultant wellbore fluid .
- 2.6 e.g. , molybdenum disulfide, tungsten disulfide, bismuth sulfide, and bismuth oxychloride
- Examples of base fluids suitable for use in conjunction with the wellbore fluids may, in some embodiments, include, but are not limited to, oil- based fluids, aqueous-based fluids, aqueous-miscible fluids, water-in-oil emulsions, or oil-in-water emulsions.
- Suitable oil-based fluids may include alkanes, olefins, aromatic organic compounds, cyclic alkanes, paraffins, diesel fluids, mineral oils, desulfurized hydrogenated kerosenes, and any combination thereof.
- Suitable aqueous-based fluids may include fresh water, saltwater (e.g.
- Suitable aqueous-miscible fluids may include, but not be limited to, alcohols, e.g., methanol, ethanol, n-propanol, isopropanol, n-butanol, sec-butanol, isobutanol, and t-butanol; glycerins; glycols, e.g. , polyglycols, propylene glycol, and ethylene glycol; polyglycol amines; polyols; any derivative thereof; any in combination with salts, e.g.
- Suitable water-in-oil emulsions also known as invert emulsions, may have an oil-to-water ratio from a lower limit of greater than about 30 : 70, 40 : 60, 50 : 50, 55 :45, 60 :40, 65 : 35, 70 : 30, 75 : 25, or 80 : 20 to an upper limit of less than about 100 :0, 95 : 5, 90 : 10, 85 : 15, 80 : 20, 75 : 25, 70 : 30, or 65 : 35 by volume in the base fluid, where the amount may range from any lower limit to any upper limit and encompass any subset therebetween.
- suitable invert emulsions include those disclosed in U .S.
- the wellbore fluids described herein may be foamed.
- the term "foam” refers to a two-phase composition having a continuous liquid phase and a discontinuous gas phase.
- the wellbore fluids may comprise a base fluid, the precipitated particles described herein, a gas, and a foaming agent.
- gases may include, but are not limited to, nitrogen, carbon dioxide, air, methane, helium, argon, and any combination thereof.
- gases may include, but are not limited to, nitrogen, carbon dioxide, air, methane, helium, argon, and any combination thereof.
- carbon dioxide foams may have deeper well capability than nitrogen foams because carbon dioxide emulsions have greater density than nitrogen gas foams so that the surface pumping pressure required to reach a corresponding depth is lower with carbon dioxide than with nitrogen .
- the higher density may impart greater particle transport capability, up to about 12 lb of particles per gal of wellbore fluid .
- the quality of a wellbore fluid that is foamed may range from a lower limit of about 5%, 10%, 25%, 40%, 50%, 60%, or 70% gas volume to an upper limit of about 95%, 90%, 80%, 75%, 60%, or 50% gas volume, and wherein the quality may range from any lower limit to any upper limit and encompasses any subset therebetween .
- the wellbore fluid that is foamed may have a foam quality from about 85% to about 95%, or about 90% to about 95%.
- foaming agents may include, but are not limited to, cationic foaming agents, anionic foaming agents, amphoteric foaming agents, nonionic foaming agents, or any combination thereof.
- suitable foaming agents may, in some embodiments, include, but are not limited to, surfactants like betaines, sulfated or sulfonated alkoxylates, alkyl quarternary amines, alkoxylated linear alcohols, alkyl sulfonates, alkyl aryl sulfonates, Ci 0 - C 2 o alkyldiphenyl ether sulfonates, polyethylene glycols, ethers of alkylated phenol, sodium dodecylsulfate, alpha olefin sulfonates such as sodium dodecane sulfonate, trimethyl hexadecyl ammonium bromide, and the like, any derivative thereof, or any combination thereof.
- the wellbore additives and/or the wellbore fluids described herein may optionally further comprise additional components, e.g., filler particles, salts, inert solids, fluid loss control agents, emulsifiers, dispersion aids, corrosion inhibitors, emulsion thinners, emulsion thickeners, viscosifying agents, gelling agents, crosslinking agents, surfactants, cement particulates, proppants, gravel particulates, lost circulation materials, pH control additives, breakers, defoaming agents, biocides, stabilizers, scale inhibitors, gas hydrate inhibitors, oxidizers, reducers, friction reducers, clay stabilizing agents, set accelerators, set retarders, and combinations thereof.
- additional components e.g., filler particles, salts, inert solids, fluid loss control agents, emulsifiers, dispersion aids, corrosion inhibitors, emulsion thinners, emulsion thickeners, viscosifying agents, gelling agents, cross
- the wellbore additives and/or the wellbore fluids described herein may be used in a plurality of wellbore operations.
- Examples of wellbore operations may, in some embodiments, include, but are not limited to, drilling operations, managed-pressure drilling operations, dual-gradient drilling, tripping operations, logging operations, lost circulation operations, stimulation operations, sand control operations, completion operations, acidizing operations, scale inhibiting operations, water-blocking operations, clay stabilizer operations, fracturing operations, gravel packing operations, wellbore strengthening operations, and sag control operations.
- the wellbore additives and/or the wellbore fluids described herein may, in some embodiments, be used in full-scale operations or pills.
- a "pill" is a type of relatively small volume of specially prepared wellbore fluid placed or circulated in the wellbore.
- Some embodiments may involve circulating a wellbore fluid that comprises a base fluid and precipitated particles described herein in a wellbore such that the wellbore fluid has a desired density and optionally a desired level of sag control .
- the wellbore fluid may be a drilling fluid, a wellbore strengthening fluid, a cementing fluid, a fracturing fluid, a plugging fluid, completion fluids, and the like and used in corresponding wellbore operations.
- the wellbore fluid may further comprise other particles like a non-precipitated weighting agent particles, proppant particles, cement particles, lost circulation particles, and the like, and any combination thereof.
- the precipitated particles may be a single type or multiple types of precipitated particles.
- the precipitated particles described herein may be useful in drilling operations. Some embodiments may involve drilling a wellbore penetrating a subterranean formation with a wellbore fluid that comprises precipitated particles described herein . In some embodiments, the precipitated particles described herein may be useful in at least one of: suspending wellbore cuttings (e.g., by contributing to the fluid viscosity and/or sag control), maintaining wellbore pressure (e.g. , by contributing to sag control), incorporating into filter cakes that provide fluid loss control, and the like. Further, precipitated particles described herein may be chosen to mitigate abrasion of wellbore tools utilized during drilling .
- the precipitated particles described herein may be useful in drilling operations. Some embodiments may involve drilling a wellbore penetrating a subterranean formation with a wellbore fluid that comprises precipitated particles described herein . In some embodiments, the precipitated particles described herein may be useful in at least one of: suspending wellbore cuttings (e.g., by contributing to the fluid viscosity and/or sag control), maintaining wellbore pressure (e.g. , by contributing to sag control), incorporating into filter cakes that provide fluid loss control, and the like. Further, precipitated particles described herein may be chosen to mitigate abrasion of wellbore tools utilized during drilling .
- the precipitated particles described herein may be used in cementing operations.
- cementing operations refers to operations where a composition is placed in a wellbore and/or a subterranean formation and sets therein to form a hardened mass, which encompasses hydraulic cements, construction cements, linked precipitated particles described herein, and some polymeric compositions that set (e.g., polymers like epoxies and latexes) .
- cementing operations may, in some embodiments, include, but are not limited to, primary cementing operations (e.g., forming cement sheaths in a wellbore annulus or forming wellbore plugs for zonal isolation or fluid diversion) and remedial cementing operations (e.g. , squeeze operations, repairing and/or sealing microannuli and/or cracks in a hardened mass, or forming plugs) .
- primary cementing operations e.g., forming cement sheaths in a wellbore annulus or forming wellbore plugs for zonal isolation or fluid diversion
- remedial cementing operations e.g. , squeeze operations, repairing and/or sealing microannuli and/or cracks in a hardened mass, or forming plugs
- cementing fluids sometimes referred to as settable compositions
- spacer fluids spacer fluids
- displacement fluids e.g., a plurality of fluids are often utilized including, but not limited to, cementing fluids (sometimes
- a cementing operation may utilize, in order, ( 1) a first spacer fluid, (2) a cementing fluid, optionally (3) a second spacer fluid, and (4) a displacement fluid, each of which may independently be a wellbore fluid comprising precipitated particles described herein .
- cementing operations may utilize a plurality of fluids in order such that each subsequent fluid has a higher density than the previous fluid .
- Achieving the desired density for a wellbore fluid in a cementing operation may, in some embodiments, involve the use of precipitated particles described herein. Further, as described herein, the precipitated particles utilized in such wellbore fluids may be chosen to achieve other properties and/or capabilities in the wellbore fluids.
- each wellbore fluid may be independently designed with precipitated particles described herein and do not necessarily require the use of the same precipitated particle in each of the wellbore fluids or the use of a precipitated particle described herein in all of the wellbore fluids.
- the first spacer fluid may include fluorite
- the cementing fluid may include precipitated manganese oxide
- the second spacer may include precipitated copper oxide.
- cementing fluids, spacer fluids, and/or displacement fluids may comprise precipitated particles described herein so as to achieve a desired density, a desired level of sag control, and/or a desired viscosity.
- linkable precipitated particles may be included in the cementing fluids and utilized so as to yield hardened masses that comprise linked precipitated particles.
- degradable precipitated particles may be included in the cementing fluids and utilized so as to yield hardened masses that that can be at least partially degraded .
- precipitated particles comprising manganese carbonate may be useful in cementing fluids to achieve a desired density and a desired level of sag control, to link in forming the hardened mass, and to degrade for increasing the permeability of the hardened mass.
- the exemplary precipitated particles and related fluids disclosed herein may directly or indirectly affect one or more components or pieces of equipment associated with the preparation, delivery, recapture, recycling, reuse, and/or disposal of the disclosed precipitated particles and related fluids.
- the disclosed precipitated particles and related fluids may directly or indirectly affect one or more components or pieces of equipment associated with an exemplary wellbore drilling assembly 200, according to one or more embodiments.
- Figure 2 generally depicts a land-based drilling assembly, those skilled in the art will readily recognize that the principles described herein are equally applicable to subsea drilling operations that employ floating or sea-based platforms and rigs, without departing from the scope of the disclosure.
- the drilling assembly 200 may include a drilling platform 202 that supports a derrick 204 having a traveling block 206 for raising and lowering a drill string 208.
- the drill string 208 may include, but is not limited to, drill pipe and coiled tubing, as generally known to those skilled in the art.
- a kelly 210 supports the drill string 208 as it is lowered through a rotary table 212.
- a drill bit 214 is attached to the distal end of the drill string 208 and is driven either by a downhole motor and/or via rotation of the drill string 208 from the well surface. As the bit 214 rotates, it creates a wellbore 216 that penetrates various subterranean formations 218.
- a pump 220 (e.g. , a mud pump) circulates drilling fluid 222
- a drilling fluid comprising the precipitated particles described herein
- a feed pipe 224 conveys the drilling fluid 222 downhole through the interior of the drill string 208 and through one or more orifices in the drill bit 214.
- the drilling fluid 222 is then circulated back to the surface via an annulus 226 defined between the drill string 208 and the walls of the wellbore 216.
- the recirculated or spent drilling fluid 222 exits the annulus 226 and may be conveyed to one or more fluid processing unit(s) 228 via an interconnecting flow line 230.
- a "cleaned" drilling fluid 222 is deposited into a nearby retention pit 232 (i. e. , a mud pit). While illustrated as being arranged at the outlet of the wellbore 216 via the annulus 226, those skilled in the art will readily appreciate that the fluid processing unit(s) 228 may be arranged at any other location in the drilling assembly 200 to facilitate its proper function, without departing from the scope of the disclosure.
- One or more of the disclosed precipitated particles may be added to the drilling fluid 222 via a mixing hopper 234 communicably coupled to or otherwise in fluid communication with the retention pit 232.
- the mixing hopper 234 may include, but is not limited to, mixers and related mixing equipment known to those skilled in the art.
- the disclosed precipitated particles may be added to the drilling fluid 222 at any other location in the drilling assembly 200.
- the retention put 232 may be representative of one or more fluid storage facilities and/or units where the disclosed precipitated particles may be stored, reconditioned, and/or regulated until added to the drilling fluid 222.
- the disclosed precipitated particles and related fluids may directly or indirectly affect the components and equipment of the drilling assembly 200.
- the disclosed precipitated particles and related fluids may directly or indirectly affect the fluid processing unit(s) 228 which may include, but is not limited to, one or more of a shaker (e.g. , shale shaker), a centrifuge, a hydrocyclone, a separator (including magnetic and electrical separators), a desilter, a desander, a separator, a filter (e.g. , diatomaceous earth filters), a heat exchanger, any fluid reclamation equipment.
- the fluid processing unit(s) 228 may further include one or more sensors, gauges, pumps, compressors, and the like used to store, monitor, regulate, and/or recondition the exemplary precipitated particles and related fluids.
- the disclosed precipitated particles and related fluids may directly or indirectly affect the pump 220, which representatively includes any conduits, pipelines, trucks, tubulars, and/or pipes used to fluidically convey the precipitated particles and related fluids downhole, with pumps, compressors, or motors (e.g. , topside or downhole) used to drive the precipitated particles and related fluids into motion, any valves or related joints used to regulate the pressure or flow rate of the precipitated particles and related fluids, and any sensors (i.e. , pressure, temperature, flow rate, etc.), gauges, and/or combinations thereof, and the like.
- the disclosed precipitated particles and related fluids may also directly or indirectly affect the mixing hopper 234 and the retention pit 232 and their assorted variations.
- the disclosed precipitated particles and related fluids may also directly or indirectly affect the various downhole equipment and tools that may come into contact with the precipitated particles and related fluids such as, but not limited to, the drill string 208, any floats, drill collars, mud motors, downhole motors and/or pumps associated with the drill string 208, and any MWD/LWD tools and related telemetry equipment, sensors or distributed sensors associated with the drill string 208.
- the disclosed precipitated particles and related fluids may also directly or indirectly affect any downhole heat exchangers, valves and corresponding actuation devices, tool seals, packers and other wellbore isolation devices or components, and the like associated with the wellbore 216.
- the disclosed precipitated particles and related fluids may also directly or indirectly affect the drill bit 214, which may include, but is not limited to, roller cone bits, PDC bits, natural diamond bits, any hole openers, reamers, coring bits, etc.
- the disclosed precipitated particles and related fluids may also directly or indirectly affect any transport or delivery equipment used to convey the precipitated particles and related fluids to the drilling assembly 200 such as, for example, any transport vessels, conduits, pipelines, trucks, tubulars, and/or pipes used to fluidically move the precipitated particles and related fluids from one location to another, any pumps, compressors, or motors used to drive the precipitated particles and related fluids into motion, any valves or related joints used to regulate the pressure or flow rate of the precipitated particles and related fluids, and any sensors (i. e. , pressure and temperature), gauges, and/or combinations thereof, and the like.
- any transport or delivery equipment used to convey the precipitated particles and related fluids to the drilling assembly 200
- any transport vessels, conduits, pipelines, trucks, tubulars, and/or pipes used to fluidically move the precipitated particles and related fluids from one location to another
- any pumps, compressors, or motors used to drive the precipitated particles and related fluids into motion
- any valves or related joints used to regulate
- drilling assembly 200 While not specifically illustrated herein, one of ordinary skill in the art should recognize the modifications to drilling assembly 200 to allow for performing other operations described herein including, but not limited to, cementing operations, fracturing operations, and fluid flow control operations.
- a wellbore drilling assembly may comprise a pump in fluid communication with a wellbore via a feed pipe; and a wellbore fluid described herein disposed in at least one selected from the group consisting of the pump, the feed pipe, the wellbore, and any combination thereof.
- a wellbore drilling assembly may comprise a pump in fluid communication with a wellbore via a feed pipe; a drill string with drill bit attached to the distal end of the drill string; and a wellbore fluid described herein in contact with the drill bit.
- a wellbore drilling assembly may comprise a pump capable of introducing a fluid into a wellbore via a feed pipe; a fluid processing unit capable of receiving the fluid from a wellbore via an interconnecting flow line; and a wellbore fluid described herein disposed in at least one selected from the group consisting of the pump, the feed pipe, the wellbore, the interconnecting flow line, the fluid processing unit, and any combination thereof.
- a wellbore drilling assembly may comprise a pump capable of introducing a fluid into a wellbore via a feed pipe; a mixing hopper upstream of the pump; and a wellbore fluid described herein disposed in at least one selected from the group consisting of the pump, the feed pipe, the wellbore, and any combination thereof.
- the mixing hopper may be useful, in some embodiments, for implementing on-the-fly changes to the wellbore fluids described herein.
- suitable wellbore fluids described herein may include, but are not limited to,
- a wellbore fluid having a density of about 7 ppg to about 50 ppg (including any subset described herein) and comprising a base fluid and a plurality of precipitated particles having a shape selected from the group consisting of ovular, substantially ovular, discus, platelet, flake, toroidal, dendritic, acicular, spiked with a substantially spherical or ovular shape, spiked with a discus or platelet shape, rod-like, fibrous, polygonal, faceted, star- shaped, and any hybrid thereof;
- Embodiments of the present invention including embodiments A,
- Embodiment A A wellbore drilling assembly comprising : a pump in fluid communication with a wellbore via a feed pipe; and a wellbore fluid disposed in at least one selected from the group consisting of the pump, the feed pipe, the wellbore, and any combination thereof, wherein the wellbore fluid has a density of about 7 ppg to about 50 ppg and comprises a base fluid and a plurality of precipitated particles having a shape selected from the group consisting of ovular, substantially ovular, discus, platelet, flake, toroidal, dendritic, acicular, spiked with a substantially spherical or ovular shape, spiked with a discus or platelet.
- Embodiment B A wellbore drilling assembly comprising : a pump in fluid communication with a wellbore via a feed pipe; a drill string with drill bit attached to the distal end of the drill string; and a wellbore fluid in contact with the drill bit, wherein the wellbore fluid has a density of about 7 ppg to about 50 ppg and comprises a base fluid and a plurality of precipitated particles having a shape selected from the group consisting of ovular, substantially ovular, discus, platelet, flake, toroidal, dendritic, acicular, spiked with a substantially spherical or ovular shape, spiked with a discus or platelet shape, rod-like, fibrous, polygonal, faceted, star-shaped, and any hybrid thereof.
- Embodiment C A wellbore drilling assembly comprising : a pump capable of introducing a fluid into a wellbore via a feed pipe; a fluid processing unit capable of receiving the fluid from a wellbore via an interconnecting flow line; and a wellbore fluid disposed in at least one selected from the group consisting of the pump, the feed pipe, the wellbore, the interconnecting flow line, the fluid processing unit, and any combination thereof, wherein the wellbore fluid has a density of about 7 ppg to about 50 ppg and comprises a base fluid and a plurality of precipitated particles having a shape selected from the group consisting of ovular, substantially ovular, discus, platelet, flake, toroidal, dendritic, acicular, spiked with a substantially spherical or ovular shape, spiked with a discus or platelet shape, rod-like, fibrous, polygonal, faceted, star-shaped, and any hybrid thereof.
- the wellbore fluid has
- Embodiments A, B, and C may include one or more of the following elements in any combination :
- Element 1 The drilling assembly wherein the wellbore fluid has a sag control of a density change of less than about 1 ppg over a time of about 10 hours to about 120 hours.
- Element 2 The drilling assembly wherein the precipitated particles have a specific gravity of about 2.6 to about 20.
- Element 3 The drilling assembly wherein the precipitated particles have a specific gravity of about 5.5 to about 20.
- Element 4 The drilling assembly wherein the precipitated particles have a median diameter of about 5 nm to about 100 microns.
- Element 5 The drilling assembly wherein the wellbore fluid further comprises a plurality of second particles, the second particles being non- precipitated .
- Element 6 The drilling assembly wherein the precipitated particles in combination with the second particles have a multiparticle specific gravity of about 3 to about 20.
- Element 7 The drilling assembly wherein the precipitated particles in combination with the second particles have a diameter distribution that has at least one mode with a standard deviation of about 2% or less of a peak diameter of the mode.
- Element 8 The drilling assembly wherein the precipitated particles in combination with the second particles have a multi-modal diameter distribution .
- Exemplary combinations include : Embodiment A, B, or C with Elements 1 and 2; Embodiment A, B, or C with Elements 3, 5, and 6; Embodiment A, B, or C with Elements 1, 5, and 7; Embodiment A, B, or C with Elements 1, 2, 5, and 8; etc.
- compositions and methods are described in terms of “comprising,” “containing,” or “including” various components or steps, the compositions and methods can also “consist essentially of” or “consist of” the various components and steps. All numbers and ranges disclosed above may vary by some amount. Whenever a numerical range with a lower limit and an upper limit is disclosed, any number and any included range falling within the range is specifically disclosed . In particular, every range of values (of the form, “from about a to about b,” or, equivalently, “from approximately a to b,” or, equivalently, “from approximately a-b”) disclosed herein is to be understood to set forth every number and range encompassed within the broader range of values.
Abstract
Description
Claims
Priority Applications (4)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
CA2907684A CA2907684A1 (en) | 2013-05-21 | 2014-03-03 | Precipitated particles and wellbore fluids and methods relating thereto |
AU2014269065A AU2014269065B2 (en) | 2013-05-21 | 2014-03-03 | Precipitated particles and wellbore fluids and methods relating thereto |
GB1516965.9A GB2527232A (en) | 2013-05-21 | 2014-03-03 | Precipitated particles and wellbore fluids and methods relating thereto |
NO20151279A NO20151279A1 (en) | 2013-05-21 | 2015-09-30 | Precipitated particles and wellbore fluids and methods related thereto |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US13/899,062 | 2013-05-21 | ||
US13/899,062 US20140209393A1 (en) | 2013-01-29 | 2013-05-21 | Precipitated Particles and Wellbore Fluids and Methods Relating Thereto |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2014189584A1 true WO2014189584A1 (en) | 2014-11-27 |
Family
ID=51933934
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2014/019818 WO2014189584A1 (en) | 2013-05-21 | 2014-03-03 | Precipitated particles and wellbore fluids and methods relating thereto |
Country Status (5)
Country | Link |
---|---|
AU (1) | AU2014269065B2 (en) |
CA (1) | CA2907684A1 (en) |
GB (1) | GB2527232A (en) |
NO (1) | NO20151279A1 (en) |
WO (1) | WO2014189584A1 (en) |
Cited By (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US9410065B2 (en) | 2013-01-29 | 2016-08-09 | Halliburton Energy Services, Inc. | Precipitated particles and wellbore fluids and methods relating thereto |
CN115784304A (en) * | 2022-12-01 | 2023-03-14 | 浙大宁波理工学院 | Fusiform Bi consisting of nanosheets 2 S 3 Method for synthesizing crystal |
CN115785921A (en) * | 2022-12-18 | 2023-03-14 | 西南石油大学 | Drilling fluid plugging material and preparation method thereof |
Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5909779A (en) * | 1997-08-19 | 1999-06-08 | M-I L.L.C. | Oil-based drilling fluids suitable for drilling in the presence of acidic gases |
US6170577B1 (en) * | 1997-02-07 | 2001-01-09 | Advanced Coiled Tubing, Inc. | Conduit cleaning system and method |
WO2007145733A1 (en) * | 2006-06-07 | 2007-12-21 | Exxonmobil Upstream Research Company | Compressible objects having a predetermined internal pressure combined with a drilling to form a variable density drilling mud |
US7677332B2 (en) * | 2006-03-06 | 2010-03-16 | Exxonmobil Upstream Research Company | Method and apparatus for managing variable density drilling mud |
US20120211227A1 (en) * | 2007-05-10 | 2012-08-23 | Halliburton Energy Services, Inc. | Well Treatment Compositions and Methods Utilizing Nano-Particles |
Family Cites Families (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3164215A (en) * | 1961-04-26 | 1965-01-05 | Howard L Johnson | Retractable drill bit and associated structures |
US7618927B2 (en) * | 1996-07-24 | 2009-11-17 | M-I L.L.C. | Increased rate of penetration from low rheology wellbore fluids |
-
2014
- 2014-03-03 CA CA2907684A patent/CA2907684A1/en not_active Abandoned
- 2014-03-03 GB GB1516965.9A patent/GB2527232A/en not_active Withdrawn
- 2014-03-03 WO PCT/US2014/019818 patent/WO2014189584A1/en active Application Filing
- 2014-03-03 AU AU2014269065A patent/AU2014269065B2/en not_active Ceased
-
2015
- 2015-09-30 NO NO20151279A patent/NO20151279A1/en not_active Application Discontinuation
Patent Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US6170577B1 (en) * | 1997-02-07 | 2001-01-09 | Advanced Coiled Tubing, Inc. | Conduit cleaning system and method |
US5909779A (en) * | 1997-08-19 | 1999-06-08 | M-I L.L.C. | Oil-based drilling fluids suitable for drilling in the presence of acidic gases |
US7677332B2 (en) * | 2006-03-06 | 2010-03-16 | Exxonmobil Upstream Research Company | Method and apparatus for managing variable density drilling mud |
WO2007145733A1 (en) * | 2006-06-07 | 2007-12-21 | Exxonmobil Upstream Research Company | Compressible objects having a predetermined internal pressure combined with a drilling to form a variable density drilling mud |
US20120211227A1 (en) * | 2007-05-10 | 2012-08-23 | Halliburton Energy Services, Inc. | Well Treatment Compositions and Methods Utilizing Nano-Particles |
Cited By (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US9410065B2 (en) | 2013-01-29 | 2016-08-09 | Halliburton Energy Services, Inc. | Precipitated particles and wellbore fluids and methods relating thereto |
CN115784304A (en) * | 2022-12-01 | 2023-03-14 | 浙大宁波理工学院 | Fusiform Bi consisting of nanosheets 2 S 3 Method for synthesizing crystal |
CN115785921A (en) * | 2022-12-18 | 2023-03-14 | 西南石油大学 | Drilling fluid plugging material and preparation method thereof |
CN115785921B (en) * | 2022-12-18 | 2024-01-30 | 西南石油大学 | Drilling fluid plugging material and preparation method thereof |
Also Published As
Publication number | Publication date |
---|---|
AU2014269065B2 (en) | 2016-06-30 |
GB201516965D0 (en) | 2015-11-11 |
GB2527232A (en) | 2015-12-16 |
CA2907684A1 (en) | 2014-11-27 |
NO20151279A1 (en) | 2015-09-30 |
AU2014269065A1 (en) | 2015-10-08 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US9322231B2 (en) | Wellbore fluids comprising mineral particles and methods relating thereto | |
US9410065B2 (en) | Precipitated particles and wellbore fluids and methods relating thereto | |
US9920604B2 (en) | Wellbore fluids comprising mineral particles and methods relating thereto | |
AU2014212523B2 (en) | Wellbore fluids comprising mineral particles and methods relating thereto | |
US20140209393A1 (en) | Precipitated Particles and Wellbore Fluids and Methods Relating Thereto | |
US20140209392A1 (en) | Wellbore Fluids Comprising Mineral Particles and Methods Relating Thereto | |
EP2951261A1 (en) | Wellbore fluids comprising mineral particles and methods relating thereto | |
US20140209390A1 (en) | Wellbore Fluids Comprising Mineral Particles and Methods Relating Thereto | |
US20140209391A1 (en) | Wellbore Fluids Comprising Mineral Particles and Methods Relating Thereto | |
US10407988B2 (en) | Wellbore fluids comprising mineral particles and methods relating thereto | |
AU2014269065B2 (en) | Precipitated particles and wellbore fluids and methods relating thereto | |
CA2907777C (en) | Wellbore fluids comprising mineral particles and methods relating thereto | |
AU2014269066B2 (en) | Wellbore fluids comprising mineral particles and methods relating thereto | |
AU2014269067B2 (en) | Wellbore fluids comprising mineral particles and methods relating thereto |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
121 | Ep: the epo has been informed by wipo that ep was designated in this application |
Ref document number: 14801667 Country of ref document: EP Kind code of ref document: A1 |
|
ENP | Entry into the national phase |
Ref document number: 2907684 Country of ref document: CA |
|
ENP | Entry into the national phase |
Ref document number: 1516965 Country of ref document: GB Kind code of ref document: A Free format text: PCT FILING DATE = 20140303 |
|
WWE | Wipo information: entry into national phase |
Ref document number: 1516965.9 Country of ref document: GB |
|
ENP | Entry into the national phase |
Ref document number: 2014269065 Country of ref document: AU Date of ref document: 20140303 Kind code of ref document: A |
|
NENP | Non-entry into the national phase |
Ref country code: DE |
|
122 | Ep: pct application non-entry in european phase |
Ref document number: 14801667 Country of ref document: EP Kind code of ref document: A1 |