WO2016164445A1 - Réduction de l'encrassement dans des fluides à base d'hydrocarbures - Google Patents
Réduction de l'encrassement dans des fluides à base d'hydrocarbures Download PDFInfo
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- WO2016164445A1 WO2016164445A1 PCT/US2016/026192 US2016026192W WO2016164445A1 WO 2016164445 A1 WO2016164445 A1 WO 2016164445A1 US 2016026192 W US2016026192 W US 2016026192W WO 2016164445 A1 WO2016164445 A1 WO 2016164445A1
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- hydrocarbon
- component
- based fluid
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- foulant
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Classifications
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- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G75/00—Inhibiting corrosion or fouling in apparatus for treatment or conversion of hydrocarbon oils, in general
- C10G75/04—Inhibiting corrosion or fouling in apparatus for treatment or conversion of hydrocarbon oils, in general by addition of antifouling agents
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- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G1/00—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
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- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G47/00—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions
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- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/80—Additives
Definitions
- the present invention relates to methods and compositions for decreasing or preventing fouling of a hydrocarbon-based fluid, and more specifically relates to methods and compositions for decreasing foulants within hydrocarbon-based fluids in a refinery.
- Lower quality feedstocks may have relatively high quantities of foulants, such as asphaltenes, coke, and coke precursors, acid gases, carbon dioxide (C0 2 ), hydrogen sulfide (H 2 S), mercaptans (R-SH), which are difficult to process and commonly cause fouling of conventional catalysts and hydroprocessing equipment.
- foulants such as asphaltenes, coke, and coke precursors, acid gases, carbon dioxide (C0 2 ), hydrogen sulfide (H 2 S), mercaptans (R-SH), which are difficult to process and commonly cause fouling of conventional catalysts and hydroprocessing equipment.
- feedstocks may possibly catch, or even surpass, higher quality crude oils, in the not-too-distant future, as the primary source of refined fossil fuels used to operate automobiles, trucks, farm equipment, aircraft, and other vehicles that rely on internal combustion.
- Hydrocracking is used in the petroleum industry to process crude oil and/or other petroleum products for commercial use by preventing or inhibiting the fouling by the foulants.
- Hydrocracking is a catalytic cracking process using an elevated partial pressure of hydrogen gas to purify the hydrocarbon stream.
- Ebullated-bed hydrocracking is one type of hydrocracking that may be used for resid conversion, and the ebullated-bed hydrocrackers may have a continuous addition and/or removal of catalysts.
- hydrocracking is subject to asphaltene precipitation as the saturates and aromatics contained in the hydrocarbon-based fluid that hold the asphaltenes in solution are removed or converted, which is driven by asphaltene-solubility chemistry.
- Fouling may occur downstream from the ebullated bed hydrocracker reactor, such as in bottom stream areas, atmospheric column bottoms, vacuum-column bottoms, vacuum-column furnaces, high- and mid-pressure separators, and the like. Extensive fouling may result in unplanned shutdowns, downtime and lost production and consequently increased operating costs.
- Asphaltenes are most commonly defined as that portion of petroleum, which is soluble in xylene and toluene, but insoluble in heptane or pentane. Asphaltenes exist in crude oil as both soluble species and in the form of colloidal dispersions stabilized by other components in the crude oil. Asphaltenes have higher molecular weights and are the more polar fractions of crude oil, and can precipitate upon pressure, temperature, and compositional changes in crude oil resulting from blending or other mechanical or physicochemical processing. Asphaltene precipitation and deposition can cause problems in subterranean reservoirs, upstream production facilities, mid-stream transportation facilities, refineries, and fuel blending operations.
- asphaltene precipitation and deposition can occur in near wellbore reservoir regions, wells, flowlines, separators, and other equipment. Once deposited, asphaltenes present numerous problems for crude oil producers. For example, asphaltene deposits can plug downhole tubulars, wellbores, choke off pipes and interfere with the functioning of safety shut-off valves, and separator equipment. Asphaltenes have caused problems in refinery processes such as desalters, crude oil distillation preheat units, and cokers.
- asphaltenes may contain nitrogen, oxygen and sulfur species, and may also contain metal species such as nickel, vanadium, and iron.
- Typical asphaltenes are known to have different solubilities in the formation fluid itself or in certain solvents like carbon disulfide or aromatic solvents, such as benzene, toluene, xylene, and the like.
- the asphaltenes are insoluble in solvents like paraffinic compounds, including but not limited to pentane, heptane, octane, etc.
- Asphal- tene stability can even be disturbed by mixing hydrocarbon-based fluids i.e.
- hydrocarbon-based fluids from different sources may be incompatible and induce destabilization of the asphaltenes therein.
- two or more hydrocarbon-based fluids may be mixed together.
- changes in physical conditions are sufficient to induce destabilization, or even the mixture of different hydrocarbon-based fluids that have incompatible chemistries.
- hydrocarbon-based fluid even if neither hydrocarbon-based fluid, alone, has destabilized foulants or the hydrocarbon-based fluid would not act as a destabilizing additive by itself, the mixing or the mixture of two or more hydrocarbon-based fluids may destabilize the foulants present in either hydrocarbon-based fluid.
- Coke is an insoluble organic portion of crude oil, distillation residua, or residua from thermal/catalytic conversion processes, such as including, but not limited to, visbreaker tar or LC finer/H oil residuum.
- Coke may have poly- aromatic hydrocarbons (PAHs) dispersed therein with a ring structure of about 4 to about 5 or more condensed aromatic rings.
- PAHs poly- aromatic hydrocarbons
- Coke precursors are the fragments that make up the coke. They are often formed by thermal cracking, dealkylation and/or dehydrogenation processes commonly used for the breaking down of complex organic molecules. They are barely soluble in the crude oil and/or residual, but they tend to precipitate. Once they precipitate, the coke precursors tend to polymerize or conglomerate and form coke.
- a method for decreasing fouling during the refining of a hydrocarbon-based fluid comprising at least one foulant.
- the method may include contacting the hydrocarbon-based fluid with an effective amount of at least one first component and an effective amount of at least one second component to decrease fouling by the at least one foulant as compared to an otherwise identical hydrocarbon-based fluid absent the first component(s) and the second component(s).
- the contacting of the hydrocarbon-based fluid with the first component(s) and the second component(s) may occur at the same time or a different time.
- the first component(s) may be or include an acrylate vinyl pyrolidinone copolymer, a succinimide, an alpha olefin and maleic anhydride reaction product, a reaction product from nonyl phenol reaction with ethylene diamine, a C 24 -C 2 8 olefin and maleic anhydride copolymer, a Mannich reaction product, a dodecyl/tert-octyl phenol resin, a sulfonic acid, an inorganic overbase, and combinations thereof.
- the second components may be or include N,N'-di-sec-butyl-p-phenylenediamine; 2,6-di-ter- butyl-4-methylphenol; 4-sec-butyl-2,6-di-tert-butylphenol; mixed tertiary butyl phenols; mixed hindered phenols; butylated hydroxytoluenes; blend of substituted p-phenylenediamines; quinones; amino-para-cresols; and combinations thereof.
- a treated hydrocracked hydrocarbon-based fluid composition may include a hydrocarbon-based fluid, at least one first component in an amount ranging from about 0.1 ppm by volume to about 10,000 ppm based on the total treated fluid, at least one second component in an amount ranging from about 0.1 ppm to about 10,000 ppm based on the total treated fluid, and at least one foulant.
- the hydrocarbon-based fluid may be or include a crude oil, a bitumen, a shale oil, a tight oil, a refinery fluid, and combinations thereof.
- the first component(s) may be or include an acrylate vinyl pyrolidinone copolymer, a succinimide, an alpha olefin and maleic anhydride reaction product, a reaction product from nonyl phenol reaction with ethylene diamine, a C 24 -C 2 8 olefin and maleic anhydride copolymer, a Mannich reaction product, a dodecyl/tert-octyl phenol resin, a sulfonic acid, an inorganic overbase, and combinations thereof.
- the second component(s) may be or include N,N'-di-sec-butyl-p-phenylenediamine; 2,6-di- ter-butyl-4-methylphenol; 4-sec-butyl-2,6-di-tert-butylphenol; mixed tertiary butyl phenols; mixed hindered phenols; butylated hydroxytoluenes; blend of substituted p-phenylenediamines; quinones; amino-para-cresols; and combinations thereof.
- the first component(s) and the second component(s) appear to decrease the amount of fouling by the foulant(s) as compared to an otherwise identical hydrocarbon-based fluid absent both the first component(s) and the second component(s).
- FIG. 1 is a graph depicting the stability of four different samples in the presence or absence of various components.
- an effective amount of at least one first component and at least one second component may decrease and/or inhibit at least one foulant within a hydrocarbon-based fluid by contacting the hydrocarbon-based fluid with the first and second component(s) or introducing the component(s) into the hydrocarbon-based fluid.
- the foulant(s) may be or include, but are not limited to, asphaltenes, coke precursors, coke, polyolefins, and combinations thereof.
- Inorganic materials such as carbon dioxide, hydrogen sulfide, mercaptans, carbonyl derivatives, and combinations thereof, if present can contribute to the total foulant content, but in non-limiting embodiment, can contribute to the total foulant content, but are generally thought to be caught in the organic matrix.
- the method thus reduces the potential of the inorganic materials to deposit and cause fouling. The formation of the organic matrix and the potential of the inorganic materials to deposit is reduced.
- the first component(s) and second component(s) may decrease, prevent, and/or inhibit the fouling by the foulant(s) therein as compared to an otherwise identical hydrocarbon-based fluid absent both the first component(s) and second component(s).
- the first components can increase the dispersion of the foulant(s) within the hydrocarbon- based fluid.
- Use of the first component(s) can be dosed into the hydrocracking fluid and decrease the aggregation and/or precipitation of the foulant(s) in a non-limiting embodiment.
- the second component(s) can inhibit the free radicals produced from the foulant(s).
- “Inhibit” is defined herein to mean that the antifoulant(s) may suppress or reduce the amount of total fouling by the foulant(s) within the hydrocarbon-based fluid, assuming there are foulant(s) present within the fluid. That is, it is not necessary for fouling to be entirely prevented for the methods and compositions discussed herein to be considered effective, although complete prevention is a desirable goal. Moreover, the fouling by the foulant(s) may be prevented or inhibited by decreasing the ability of the foulant(s) from polymerizing or otherwise agglomerating, reducing the ability of the foulant(s) to form deposits or precipitates, and the like.
- the methods described are considered successful if the first components) and the second component(s) together decrease an amount of fouling than would otherwise occur in the absence of the first and second components. Alternatively, success is obtained if a majority of the fouling is decreased or inhibited or inactivated, i.e. at least 51 wt%, alternatively from about 70 wt% independently to about 99.9 wt%, or from about 90 wt% independently to about 96 wt% in another non-limiting embodiment.
- the foulants may or may not already exist in the hydrocarbon-based fluid prior to refining (e.g. hydrocracking) of the hydrocarbon-based fluid.
- asphaltenes may crack and/or polymerize during the reaction process of hydrocracking.
- the foulant(s) may precipitate, or the asphaltenes may form into coke precursors and possibly coke, in a non-limiting embodiment.
- the first component(s) may be or include, but is not necessarily limited to, an acrylate vinyl pyrolidinone copolymer, a succinimide, an alpha olefin and maleic anhydride reaction product, a reaction product from nonyl phenol reaction with ethylene diamine (EDA), a C 24 -C 2 8 olefin and maleic anhydride copolymer, a Mannich reaction product, a dodecyl/tert-octyl phenol resin, a sulfonic acid, an inorganic overbase, and combinations thereof.
- EDA ethylene diamine
- Non- limiting examples of the Mannich reaction product may be or include, but are not necessarily limited to tetraethylenepentamine (TEPA), aromatic amine derivatives, poly alkyl amine, and combinations thereof.
- Non-limiting examples of the sulfonic acid may be or include dodecylbenzenesulfonic acid (DDBSA), polyalkylsulfonic acid, polyaromaticsulfonic acid, and combinations thereof.
- Non-limiting examples of the inorganic overbase may be or include, but are not necessarily limited to magnesium sulfonates, magnesium oxides, magnesium carboxylates, calcium sulfonates, calcium oxides, calcium carbox- ylates, and combinations thereof.
- Overbase refers to where the amount of base is more than the amount of metal within the first component.
- the inorganic overbase refers to inorganic compounds with a great capacity of neutralizing acids. For example, when a magnesium oxide over- base is used as a first component, the amount of oxide is lower than the amount of magnesium to form the inorganic overbase.
- the inorganic overbase may be prepared in any manner known to those of ordinary skill in the art.
- the second component(s) may be or include, but is non-limiting embodiment not limited to, N, N'-di-sec-butyl-p-phenylenediamine; 2,6-di-ter- butyl-4-methylphenol; 4-sec-butyl-2,6-di-tert-butylphenol (e.g. ISONOX ® 132); mixed tertiary butyl phenols (e.g. ISONOX ® 133); mixed hindered phenols; butylated hydroxytoluene (BHT); blend of substituted p-phenylenediamines (e.g. NAUGARD ® R); quinones; amino-para-cresols; and combinations thereof.
- N, N'-di-sec-butyl-p-phenylenediamine 2,6-di-ter- butyl-4-methylphenol
- 4-sec-butyl-2,6-di-tert-butylphenol e.g. ISONOX ®
- Non-limiting examples of the mixed hindered phenols include polyalkyl substituted phenol, hydroquinone derivatives, and combinations thereof.
- Non-limiting examples of the quinones may be or include substituted alkyl quinone, benzo- quinone derivatives, substituted quinone methide, and combinations thereof.
- a non-limiting example of the amino-para-cresol may be or include nitroso phenol derivatives.
- first component(s) and the second component(s) may contact or be introduced into the hydrocarbon-based fluid as an additive mixture (i.e. at the same time), or at different times.
- first component and second component are not used herein to denote an order that the components must be added; “first” and “second” are simply used to distinguish the two groups of chemicals from each other. Said differently, the “second component” may be added before the "first component”.
- the effective amount of the first component(s) and the second components) is difficult to predict in advance because it would depend on the particular hydrocarbon-based fluid, the type of targeted foulant, the operating conditions (e.g. temperature), and the like.
- the effective amount of the first component(s) may range from about 1 ppm independently to about 10,000 ppm based on the total hydrocarbon-based fluid.
- the amount of the first component(s) may range from about 10 ppm independently to about 1 ,000 ppm, or from about 50 ppm independently to about 300 ppm, in another non-limiting embodiment.
- "independently" means that any lower threshold may be used together with any upper threshold to give a suitable alternative range.
- the effective amount of the second component(s) may range from about 1 ppm independently to about 10,000 ppm based on the total hydrocarbon-based fluid.
- the amount of the second component(s) may range from about 10 ppm independently to about 1 ,000 ppm, or from about 50 ppm independently to about 300 ppm, in another non-limiting embodiment.
- the volume ratio of the formulated product of the first component to the second component may range from about 1 : 1 independently to about 1 :20, alternatively from about 2: 1 independently to about 20: 1 .
- the first component(s) and second component(s) may be introduced into the hydrocarbon stream at one or more of a variety of locations, such as but not limited to, upstream from or into an ebullated bed hydrocracking unit (e.g. an LC finer or H-oil reactor), into an interstage separator, into a crude oil vacuum distillation unit, into an atmospheric crude oil distillation units, and combinations thereof.
- an ebullated bed hydrocracking unit e.g. an LC finer or H-oil reactor
- the first component(s) and second component(s) may be added into the hydrocarbon-based fluid by adding them into a distillate fluxant blended with a distillate residua feed, adding them into the hydrocracking unit feed by a connected feed line, and combinations thereof.
- the first component(s) and second component(s) may be added into the hydrocarbon- based fluid at a pre-determined rate, which may be a continuous rate, an intervallic rate, an intermittent rate, and combinations thereof.
- “Distillate fluxant” is used herein to refer to an atmospheric or vacuum distillation cut or distillate from a conversion process, such as but not limited to gasoline, kerosene, gas oil, vacuum gas oil, visbreaker gas oil, FCC light cycle oil, FCC slurry oil, and the like.
- hydrocracking is defined herein to mean a process where the primary purpose is to decrease the boiling range of a heavy oil feedstock and where a substantial portion of the feedstock is converted into products with boiling ranges lower than that of the original feedstock.
- Hydrocracking generally involves fragmentation of larger hydrocarbon molecules into smaller molecular fragments having a fewer number of carbon atoms and a higher hydrogen- to-carbon ratio.
- Hydrocracking may involve the formation of hydrocarbon free radicals during fragmentation, which may be followed by capping the free radical ends or moieties with hydrogen.
- the hydrogen atoms or radicals that react with hydrocarbon free radicals during hydrocracking may be generated at or by active catalyst sites of an ebullated bed hydrocracking unit.
- the operating conditions of the hydrocarbon-based fluid may require the temperature, pressure, and the like to be within a particular range.
- the temperature of the hydrocarbon-based fluid may range from about 25 °C independently to about 500 °C, alternatively from about 50 °C independently to about 250 °C.
- the pressure surrounding the hydrocarbon-based fluid may range from about 0 bars (0 kPa); independently to about 250 bars (approximately 25,000 kPa); alternatively from about 10 bars (1 ,000 kPa) independently to about 200 bars (approximately 20,000 kPa).
- the hydrocarbon-based fluid may be a still fluid, or it may be part of a hydrocarbon feed or hydrocarbon-based fluid or flowing stream; "hydrocarbon- based fluid” is defined herein to include both.
- the hydrocarbon fluid may be a liquid, a gas, or a combination thereof.
- Non- limiting examples of the hydrocarbon-based fluid may be or include a crude oil, a bitumen, a shale oil, a tight oil, a refinery fluid, and combinations thereof.
- the crude oil may a combination or mixture of at least two different crude oils.
- "Crude oil” as used herein includes water-in-crude emulsions, a fluid that is only crude oil, and mixtures thereof.
- FIG. 1 is a graph depicting the stability of four different samples in the presence or absence of various components.
- Sample 1 included a shale oil without the addition of the first component nor the second component.
- Sample 2 included the same shale oil in the presence of 3000 ppm of the first component, which was an alpha olefin copolymer.
- Sample 3 included the same shale oil in the presence of 3000 ppm of the first component and the second component, which were the alpha olefin copolymer and a blended phenolic antioxidant.
- Sample 4 included the same shale oil in the presence of 3000 ppm of the second component, which was a blended phenolic antioxidant.
- IPV inflection point value
- the near infrared transmittance data obtained from the hydrocarbon-based fluid was plotted on the graph vs. volume of non-solvent added.
- the maximum inflection point value is the representative value of the amount of non-solvent required to cause the foulants (e.g. asphaltenes and/or polynuclear aromatics in this instance) in the hydrocarbon-based fluid to become unstable and precipitate.
- the more non-solvent added correlates to a more stable hydrocarbon-based fluid.
- sample 3 (the shale oil, the first component, and the second component) using the composition and method described herein was the most stable.
- Hydrocarbon fluids that contain little to no asphaltenes and/or polynuclear aromatics may form asphaltenes and/or polynuclear aromatics upon heating.
- a thermal stress test in the case of a hydrocarbon- based fluid e.g. a shale oil in a non-limiting example
- Heating stressing of the sample may be required if the samples do not have sufficient asphaltenes to see a flocculation point in the titration test on the crude sample as received.
- Shale oils are very paraffinic in nature and they inherently destabilize asphaltenes and cannot support them in solution.
- PNAs poly-nuclear aromatics
- the heating, or thermal stressing, in the test is required to evaluate this potential effect and to evaluate the additives on that effect for crude samples that do not generate a detectable floe point as received.
- first components specific second components, hydrocarbon-based fluids, foulants, proportions, addition procedures, and locations within a refinery where the components may contact the hydrocarbon- based fluid falling within the claimed parameters, but not specifically identified or tried in a particular composition or method, are expected to be within the scope of this invention.
- the present invention may suitably comprise, consist of or consist essentially of the elements disclosed and may be practiced in the absence of an element not disclosed.
- the method for decreasing fouling during the refining of a hydrocarbon-based fluid comprising at least one foulant may consist of or consist essentially of contacting the hydrocarbon-based fluid with an effective amount of at least one of a first component and an effective amount of at least one of a second component to decrease fouling by the foulant(s) as compared to an otherwise identical hydrocarbon-based fluid absent the first component(s) and the second component(s); the contacting of the hydrocarbon-based fluid with the first component(s) and the second components) may occur at the same time or a different time;
- the first component(s) may be or include an acrylate vinyl pyrolidinone copolymer, a succinimide, an alpha olefin and maleic anhydride reaction product, a reaction product from nonyl phenol reaction with ethylene diamine, a C 24 -C 2 8 o
- the treated hydrocracked hydrocarbon-based fluid composition may suitably comprise, consist of or consist essentially of a hydrocarbon-based fluid, at least one first component in an amount ranging from about 0.1 ppm to about 10,000 ppm based on the total treated fluid, at least one second component in an amount ranging from about 0.1 ppm to about 10,000 ppm based on the total treated fluid, and at least one foulant;
- the hydrocarbon-based fluid may be or include a crude oil, a bitumen, a shale oil, a tight oil, a refinery fluid, and combinations thereof;
- the first component(s) may be or include an acrylate vinyl pyrolidinone copolymer, a succinimide, an alpha olefin and maleic anhydride reaction product, a reaction product from nonyl phenol reaction with ethylene diamine, a C 24 -C 2 8 olefin and maleic anhydride copolymer, a Mannich reaction product, a dodecyl
- the term “may” with respect to a material, structure, feature or method act indicates that such is contemplated for use in implementation of an embodiment of the disclosure and such term is used in preference to the more restrictive term “is” so as to avoid any implication that other, compatible materials, structures, features and methods usable in combination therewith should or must be, excluded.
- the term "substantially" in reference to a given parameter, property, or condition means and includes to a degree that one of ordinary skill in the art would understand that the given parameter, property, or condition is met with a degree of variance, such as within acceptable manufacturing tolerances.
- the parameter, property, or condition may be at least 90.0% met, at least 95.0% met, at least 99.0% met, or even at least 99.9% met, regardless of the type of percentage.
Abstract
La présente invention concerne une quantité efficace d'au moins un premier constituant et une quantité efficace d'au moins un second constituant qui peuvent entrer en contact avec un fluide à base d'hydrocarbures ou être introduit dans un fluide à base d'hydrocarbures comportant au moins un agent d'encrassement destiné à diminuer l'encrassement au moyen du ou des agents d'encrassement par comparaison avec un autre fluide à base d'hydrocarbures identique absent du ou des premiers constituants et du ou des seconds constituants. Dans un mode de réalisation non limitatif, le ou les premiers constituants peuvent être considérés comme un dispersant, et le ou les seconds constituants peuvent être considérés comme des inhibiteurs de radicaux libres.
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KR1020177032183A KR20180011082A (ko) | 2015-04-08 | 2016-04-06 | 탄화수소-계 유체 내 오염 감소 |
EP16777189.8A EP3280784A4 (fr) | 2015-04-08 | 2016-04-06 | Réduction de l'encrassement dans des fluides à base d'hydrocarbures |
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US15/090,912 US20160298039A1 (en) | 2015-04-08 | 2016-04-05 | Decreasing fouling in hydrocarbon-based fluids |
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WO2018106770A1 (fr) * | 2016-12-07 | 2018-06-14 | Ecolab USA, Inc. | Compositions antisalissures pour charges pétrolières à traiter |
US10704000B2 (en) | 2016-12-07 | 2020-07-07 | Ecolab Usa Inc. | Polymeric dispersants for petroleum process streams |
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US11280779B2 (en) | 2017-12-18 | 2022-03-22 | Championx Usa Inc. | Solvency for asphaltene deposit remediation or inhibition |
CA3064231A1 (fr) * | 2018-12-20 | 2020-06-20 | Infineum International Limited | Procede anti-encrassement et/ou d`agglomeration d`asphalte dans le petrole |
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2016
- 2016-04-05 US US15/090,912 patent/US20160298039A1/en not_active Abandoned
- 2016-04-06 EP EP16777189.8A patent/EP3280784A4/fr not_active Withdrawn
- 2016-04-06 WO PCT/US2016/026192 patent/WO2016164445A1/fr unknown
- 2016-04-06 KR KR1020177032183A patent/KR20180011082A/ko not_active Application Discontinuation
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Cited By (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2018106770A1 (fr) * | 2016-12-07 | 2018-06-14 | Ecolab USA, Inc. | Compositions antisalissures pour charges pétrolières à traiter |
KR20190091450A (ko) * | 2016-12-07 | 2019-08-06 | 에코랍 유에스에이 인코퍼레이티드 | 석유 공정 스트림을 위한 항파울링 조성물 |
US10704000B2 (en) | 2016-12-07 | 2020-07-07 | Ecolab Usa Inc. | Polymeric dispersants for petroleum process streams |
US11396632B2 (en) | 2016-12-07 | 2022-07-26 | Ecolab Usa Inc. | Antifouling compositions for petroleum process streams |
KR102547899B1 (ko) | 2016-12-07 | 2023-06-23 | 에코랍 유에스에이 인코퍼레이티드 | 석유 공정 스트림을 위한 항파울링 조성물 |
Also Published As
Publication number | Publication date |
---|---|
EP3280784A4 (fr) | 2018-09-05 |
US20160298039A1 (en) | 2016-10-13 |
KR20180011082A (ko) | 2018-01-31 |
EP3280784A1 (fr) | 2018-02-14 |
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