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Небесная энциклопедия

Космические корабли и станции, автоматические КА и методы их проектирования, бортовые комплексы управления, системы и средства жизнеобеспечения, особенности технологии производства ракетно-космических систем

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Мониторинг СМИ

Мониторинг СМИ и социальных сетей. Сканирование интернета, новостных сайтов, специализированных контентных площадок на базе мессенджеров. Гибкие настройки фильтров и первоначальных источников.

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Поддерживает ввод нескольких поисковых фраз (по одной на строку). При поиске обеспечивает поддержку морфологии русского и английского языка
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Применить Всего найдено 1958. Отображено 100.
10-05-2012 дата публикации

Polymeric corrosion inhibitors

Номер: US20120114523A1
Автор: Natalija Gorochovceva, Per-Erik Hellberg
Принадлежит: Akzo Nobel Chemicals International BV

The present invention relates to the use of a product obtainable by the reaction of an alkoxylated fatty amine having the formula (I) wherein R is a hydrocarbyl group having 8-24 carbon atom; each B is, independently, an alkyl group having 1-4 carbon atoms, a benzyl group, or the group (AO) n H, wherein A is an alkylene group containing 2-4 carbon atoms, preferably 2 carbon atoms; each n is at least 1 and the sum of all n is 2-30; x is 2 or 3; and y is 0-3, preferably 0 or 1; or of a product obtainable by partial or total quaternisation of the alkoxylated fatty amine of formula (I); with a dicarboxylic acid derivative having the formula (IIa) or (IIb) wherein D is —OH, —Cl, or —OR3, wherein R3 is a C1-C4 alkyl group; R2 is an alkylene radical of formula —(CH 2 ) z —, wherein z is an integer from 0 to 10, preferably from 2 to 4, and most preferably 2, and wherein the alkylene radical may be substituted by 1 or 2 —OH groups; the group —CH═CH—, or the o-phenylene group; or by reacting a product (I) with a dicarboxylic acid derivative (IIa) or (IIb), followed by partial or total quaternisation of the reaction product obtained; or by reacting a product (I) with a dicarboxylic acid derivative (IIa) or (IIb), followed by partial or total quaternisation of the reaction product obtained, wherein the product consists to >60% w/w of oligomers/polymers with at least two alkoxylated amine units and one or more diacid/acid anhydride unit and to >50% w/w of oligomers/polymers with at least two alkoxylated amine units and two or more diacid/acid anhydride units; as a corrosion inhibitor for metal surfaces. The invention also relates to a method for protecting a metal surface from corrosion by contacting the metal surface with said corrosion inhibitor.

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Номер записи: 1
17-05-2012 дата публикации

Metallic Composite Comprising a Load-Bearing Member and a Corrosion Resistant Lager

Номер: US20120121930A1
Автор: Kenneth Göransson, Mats Lundberg
Принадлежит: Sandvik Intellectual Property AB

A composite material intended for components used in corrosive environments, wherein said material comprises a corrosion-resistant part and a load-bearing part, wherein said parts are disposed adjacent one another, wherein the corrosion-resistant part is a copper-aluminium alloy (Cu/Al) and wherein the load-bearing part is comprised of an iron-based (Fe), a nickel-based (Ni) or a cobalt-based (Co) alloy. The invention is characterized in that the diffusion barrier is disposed between the corrosion-resistant part and the load-bearing part, and in that the diffusion barrier contains one of the substances chromium (Cr) or iron (Fe) or iron (Fe) that contains one of the alloying substances chromium (Cr) or carbon (C).

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Номер записи: 2
11-04-2013 дата публикации

Removing Amines from Hydrocarbon Streams

Номер: US20130087480A1
Автор: Boyd Walter A., Duggan George G., Stark Joseph L., Weers Jerry J.
Принадлежит: BAKER HUGHES INCORPORATED

Corrosive amine salts in hydrocarbon streams such as desalted crude oil streams can be prevented or avoided by adding certain amine scavenging chemicals to the streams to remove the amines therefrom. Suitable amine scavengers include, but are not necessarily limited to, carboxylic anhydrides and copolymers of carboxylic anhydrides, aromatic anhydrides, isocyanates, polyisocyanates, and epoxides. The non-corrosive reaction products of the amines and/or ammonia with these scavengers are preferably oil-soluble, non-basic and thermally stable. The amine scavengers bind up and react with the amines and/or ammonia to keep them from reacting with materials such as acids (e.g. HCl) to form corrosive amine salts. 2. The treated hydrocarbon stream of where the at least one non-corrosive reaction product is oil-soluble claim 1 , non-basic and thermally stable.3. The treated hydrocarbon stream of where the effective amount of amine scavenger is at least approximately stoichiometrically functionally equivalent to the nitrogen compound present in the hydrocarbon stream.4. The treated hydrocarbon stream of where the effective amount of amine scavenger is greater than 100 ppm based on the hydrocarbon.5. The treated hydrocarbon stream of where the hydrocarbon stream is a desalted crude oil stream.6. The treated hydrocarbon stream of where the amine scavenger has a molecular weight greater than 2 claim 1 ,500.8. The treated hydrocarbon stream of where the effective amount of amine scavenger is greater than 100 ppm based on the hydrocarbon.9. The treated hydrocarbon stream of where the hydrocarbon stream is a desalted crude oil stream.10. The treated hydrocarbon stream of where the amine scavenger has a molecular weight greater than 2 claim 7 ,500.12. The treated desalted crude oil stream of where the at least one non-corrosive reaction product is oil-soluble claim 11 , non-basic and thermally stable.13. The treated desalted crude oil stream of where the effective amount of amine ...

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Номер записи: 3
17-10-2013 дата публикации

METHOD, APPARATUS AND CHEMICAL PRODUCTS FOR TREATING PETROLEUM EQUIPMENT

Номер: US20130270157A1
Автор: FERRARA Marcello
Принадлежит:

The present invention provides a method, an apparatus and chemical products for treating petroleum equipment wherein a fluid is flowing, preferably of the hydrocarbon type, and wherein treating is performed by establishing a closed or semi-closed flow circulation loop, during the normal production operations of the equipment. The treatment can refer to the cleaning of equipment, to yield improvement as compared to normal run conditions and/or to a reduction of coke formation and/or to coke removal on catalysts. 1. A method for treating a petroleum plant or equipment of the petroleum plant during a running of the petroleum plant , comprising:maintaining, during a treatment period, the petroleum plant under a production operating condition, typical of the plant itself, which includes providing fresh feed to the petroleum plant;while maintaining the petroleum plant under the production operating condition, there is carried out one or both of a) and b);a) introducing in the petroleum plant, during the treatment period, a hydrocarbon-based treatment fluid;b) varying an established feed rate, present at initiation of the treatment of the petroleum plant or equipment of the petroleum plant, which established feed rate ranges from a maximum operation rate for the petroleum plant, which is inclusive of a design rate for the petroleum plant, to a minimum operation rate which is set at a level for satisfying a minimum production operating state in the petroleum plant;wherein said introduction of a hydrocarbon-based treatment fluid and/or said variation to the treatment feed rate generates an additional source or sources for distallation with respect to the amount provided by the established rate; anddistilling said additonal source or sources for distillation for the purpose of plant treatment.2. The method of wherein the additional source or sources of distillate generated by the variation to the treatment feed rate is fed into the current fresh feed of the plant as the ...

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Номер записи: 4
24-10-2013 дата публикации

Treatment process for an isomerization unit

Номер: US20130276825A1
Автор: Dana K. Sullivan, Jocelyn C. Daguio, Ralph Charles Norton
Принадлежит: UOP LLC

One exemplary embodiment can be a process for treating an interior of equipment for an isomerization unit. Generally, the isomerization unit includes at least one of a drying zone, an isomerization reaction zone, and a stabilizer zone, for receiving a feed stream. Usually, the feed stream includes one or more C4-C8 hydrocarbons. The process can include combining an anhydrous hydrogen stream and anhydrous organic chloride stream to form a hydrogen chloride feedstock, and passing the hydrogen chloride feedstock to a reaction zone containing a catalyst including at least one of nickel, palladium, and platinum on an alumina support to form a hydrogen chloride stream, and passing the hydrogen chloride stream upstream of the isomerization reaction zone.

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Номер записи: 5
26-12-2013 дата публикации

Process for prediciting the stability of crude oil and employing same in transporting and/or refining the crude oil

Номер: US20130341241A1
Автор: Corina L. Sandu, Gavin M. MEDINE, Giuseppe Della Sala, Marco Respini, Sai Reddy Pinappu
Принадлежит: Baker Hughes Inc

A process for refining crude oil can be controlled to mitigate fouling by deploying a refractive index probe at a location suitable for making a crude oil stability determination, wherein the crude oil stability determination is relevant to controlling the refining process; making a measurement of crude oil stability; and then controlling the process for refining crude oil by maintaining the process or implementing a change to the process, based upon the determination of crude oil stability. This concept can also be applied to transporting, blending, and storing crude oil.

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Номер записи: 6
20-02-2014 дата публикации

Method of applying coating composition of quaternary ammonium salts containing non-halogen anions as anticorrosive agents

Номер: US20140050926A1
Автор: Joseph Kimler, Joseph William Scheblein, Larry K. Hall, Michael Yao-Chi Chiang
Принадлежит: Lonza LLC

Disclosed are quaternary ammonium salts containing non-halogen anions (e.g., quaternary ammonium carbonates, bicarbonates, and mixtures thereof) as anti-corrosive agents. The invention relates to a method for inhibiting the corrosion of metal surfaces by applying a composition containing one or more quaternary ammonium carbonate or bicarbonate. The disclosure is also directed to anti-corrosive coatings for metal substrates containing these compounds, to metal substrates having these anticorrosive coatings, and to aqueous cleaning solutions containing these compounds.

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Номер записи: 7
06-03-2014 дата публикации

Process for Reducing the Asphaltene Yield and Recovering Waste Heat in a Pyrolysis Process by Quenching with a Hydroprocessed Product

Номер: US20140061100A1
Автор: Bhasker Ananthakrishnan, Jacob Linelle F., Lattner James R., Reed Keith G., Xu Teng
Принадлежит:

The invention relates to upgraded pyrolysis products, processes for upgrading products obtained from hydrocarbon pyrolysis, equipment useful for such processes, and the use of upgraded pyrolysis products. 1. A hydrocarbon quenching process , comprising:(a) providing a first mixture comprising ≧10.0 wt. % hydrocarbon based on the weight of the first mixture;{'sub': 2', '1, '(b) pyrolyzing the first mixture to produce a second mixture comprising ≧1.0 wt. % of Cunsaturates and ≧1.0 wt. % tar based on the weight of the second mixture, the second mixture and having a first temperature T;'}{'sub': 2', '1', 'z', '1', '2, '(c) adding a quench fluid to the second mixture to produce a quenched mixture having a second temperature T, wherein (i) T>T, (ii) T−T≧100.0° C., and (iii) at least a portion of the resulting quenched mixture is liquid;'}(d) separating from the quenched mixture a vapor stream and a tar stream; and(e) contacting at least a first portion of the tar stream with at least one hydroprocessing catalyst under catalytic hydroprocessing conditions in the presence of molecular hydrogen to produce a hydroprocessed product, wherein the quench fluid comprises ≧5.0 wt. % of the hydroprocessed product based on the weight of the quench fluid.2. The process of claim 1 , wherein the quench fluid further comprises a second portion of the tar stream in an amount ≧10.0 wt. % based on the weight of the quench fluid.3. The process of claim 2 , wherein the second portion of the tar stream bypasses the hydroprocessing of step (e).4. The process of claim 1 , wherein the hydroprocessed product comprises ≧10.0 wt. % of a hydroprocessed tar and ≧10.0 wt. % of a low-boiling mixture claim 1 , the low boiling mixture having an ASTM D86 10% distillation point ≧60.0° C. and a 90% distillation point ≦350.0° C.5. The process of claim 1 , wherein the first temperature Tis in the range of 600° C. to 850° C.6. The process of claim 1 , wherein the second temperature Tis in the range of 250° C. ...

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Номер записи: 8
03-04-2014 дата публикации

AQUEOUS POUR POINT DEPRESSANT DISPERSION COMPOSITION

Номер: US20140094537A1
Автор: Bioxom Stephanie A., Kuhlman Roger L., Michalowski Jeffrey D., Mielcarek Melissa A., Schmidt Dale C., Strandburg Gary M.
Принадлежит: Dow Global Technologies LLC

The present invention relates to an aqueous pour point depressant dispersion composition comprising a thermoplastic polymer, preferably ethylene vinyl acetate (EVA); a dispersing agent; water; optionally an aqueous freezing point depressant; and optionally a stabilizing agent wherein the volume average particle size of the dispersed thermoplastic polymer is equal to or less than 1 micrometers and a method to make and use said composition. 2. The aqueous pour point depressant dispersion composition of wherein the average particle size of the dispersed EVA is equal to or less than 1 micrometer claim 1 , the amount of dispersing agent in the final composition is from 1 to 10 weight percent claim 1 , and the water:aqueous freezing point depressant mixture in the final composition is present in an amount of from 40 to 75 weight percent claim 1 , the water:aqueous freezing point depressant ratio is from 40:60 to 70:30.3. The aqueous pour point depressant dispersion composition of further comprising:v a stabilizing agent in an amount of from 0.5 weight percent to 5 weight percent.4. The aqueous pour point depressant dispersion composition of wherein the polymer i is an ethylene vinyl acetate copolymer with 28 to 32 weight percent vinyl acetate claim 1 , and a melt index (determined according to ASTM D1238 at 190° C. and 2.16 kg) of 43 g/10 min.5. The aqueous pour point depressant dispersion composition of wherein the polymer i is an ethylene vinyl acetate copolymer with 40 weight percent vinyl acetate claim 1 , and a melt index (determined according to ASTM D1238 at 190° C. and 2.16 kg) of 52 g/10 min.6. The aqueous pour point depressant dispersion composition of wherein the dispersing agent ii comprises one or more of:{'sub': 1', '2', '1', '2, 'a a fatty acid/salt having the formula RCOORwherein Ris a straight chain, saturated or unsaturated, hydrocarbon radical of 8 to 25 carbon atoms and Ris H or a base-forming radical;'}b an alkyl, arene and/or alkylarene sulfonate;c a ...

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Номер записи: 9
05-01-2017 дата публикации

COATING COMPOSITION FOR INHIBITING BUILD-UP OF CARBONACEOUS MATERIAL AND APPARATUS COMPRISING THE COATING AND METHOD

Номер: US20170001913A1
Автор: Gu Yanfei, GUO Minghu, Kool Lawrence Bernard, Peng Wenqing, Wang Shizhong, Xu Wusheng, Yang Zhaohui, Zhou Hong
Принадлежит:

A composition useful in methods and apparatuses for inhibiting the build-up of byproduct carbonaceous material includes a perovskite material or a precursor therefor; and a yttrium doped ceria or a precursor therefor. 1. A composition comprising:a perovskite material or a precursor therefor; anda yttrium doped ceria or a precursor therefor.2. The composition of claim 1 , wherein the perovskite material is of formula ABO claim 1 , wherein0.9 Подробнее

Номер записи: 10
02-01-2020 дата публикации

GAS HYDRATE INHIBITORS

Номер: US20200002598A1
Автор: Balestrini Andrea, Floridi Giovanni, Giardini Lorenzo, Li Bassi Giuseppe, PARINI Mauro
Принадлежит: LAMBERTI SPA

The present invention relates to a method to inhibit gas hydrate formation in the field of crude oil and natural gas extraction, transportation and processing. 2. The method of claim 1 , wherein claim 1 , in the quaternary ammonium amide salt of formula I claim 1 , R(CO)— is the residue of a saturated or unsaturated claim 1 , linear or branched aliphatic carboxylic acid wherein at least 60% by weight of said acid contain less than 16 carbon atoms.3. The method of claim 1 , wherein claim 1 , in the quaternary ammonium amide salt of formula I claim 1 , Rand Rare the same and are a butyl group.4. The method of claim 1 , wherein claim 1 , in the quaternary ammonium amide salt of formula I claim 1 , Ris linear or branched alkyl group having from 2 to 4 carbon atoms.5. The method of claim 4 , wherein Ris linear or branched alkyl group having 2 or 3 carbon atoms.6. The method of claim 1 , comprising adding to the mixture of hydrocarbons and water of the quaternary ammonium amide salt of formula I as a composition comprising between 20 and 95% by weight of said salt claim 1 , a solvent and other optional additives.7. The method of claim 6 , wherein the composition comprises between 45 and 90% by weight of said quaternary ammonium amide salt.8. The method of claim 1 , comprising adding to the mixture of hydrocarbons and water of between 0.1 and 8.0% by weight of quaternary ammonium amide salt of formula I.9. The method of claim 8 , comprising of adding between 0.5 and 5.0% by weight of said quaternary ammonium amide salt. The present invention relates to a method to inhibit gas hydrate formation in the field of oil and natural gas extraction, transportation and processing.Gas hydrates (or clathrate hydrates, gas clathrates, clathrates, etc.) are crystalline water-based solids physically resembling ice, in which small non-polar hydrocarbon molecules (typically gases) are trapped inside “cages” of hydrogen bonded water molecules. In other words, gas hydrates are clathrate ...

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Номер записи: 11
04-01-2018 дата публикации

COMPOUNDS AND METHODS FOR INHIBITING CORROSION IN HYDROCARBON PROCESSING UNITS

Номер: US20180002619A1
Автор: Devi Rebika Mayanglambam, Ghosh Romit, Joshi Manish, Kesavan Sathees, Nagu Muthukumar, Patel Nimeshkumar Kantilal, Shetty Ashok Shankar, Subbiah Alagarsamy
Принадлежит:

Treatment compositions for neutralizing acidic species and reducing hydrochloride and amine salts in a fluid hydrocarbon stream are disclosed. The treatment compositions may comprise at least one amine with a salt precipitation potential index of equal to or less than about 1.0. Methods for neutralizing acidic species and reducing deposits of hydrochloride and amine salts in a hydrocarbon refining process are also disclosed. The methods may comprise providing a fluid hydrocarbon stream and adding a treatment composition to the fluid hydrocarbon stream. The treatment compositions used may have a salt precipitation potential index of equal to or less than about 1.0 and comprise either water-soluble or oil-soluble amines. 1. A treatment composition for neutralizing acidic species and reducing hydrochloride and amine salts in a fluid hydrocarbon stream , said treatment composition comprising at least one amine selected from the group consisting of , 1 ,2 dimethylpropylamine , 1 ,4-dimethylpiperazine , N-methyldibutylamine , N-methyldipropylamine , ethylhexylamine , N-methylpyrrolidine , di-ethyl hydroxyl amine , dimethylcyclohexylamine , diethylpropargylamine , dimethyl-N-propylamine , di-N-propylamine , N ,N ,N′ ,N′-tetramethylethylenediamine (TMED) , N-methyl piperidine , 2-dimethylamino 2-methyl 1-propanol (DMAMP) , N ,N ,N′ ,N′-tetramethyldiaminomethane (TMMD) , dimethyl tertiary butanolamine (DMTBA) , dimethyl methoxypropylamine (DMMOPA) , furfurylamine , and combinations thereof; and wherein said amine has a salt precipitation potential index of equal to or less than about 1.0.2. The treatment composition of claim 1 , wherein said amine has a pKa equal to or greater than about 5.0.3. The treatment composition of claim 1 , wherein said amine has a salt precipitation potential index of equal to or less than about 0.5.4. The treatment composition of claim 1 , wherein said treatment composition further comprises at least one water soluble amine.5. The treatment ...

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Номер записи: 12
03-01-2019 дата публикации

Refinery Antifoulant Process

Номер: US20190002775A1
Автор: Kerby Paul, Maranski Krzysztof J., Sutkowski Andrew C.
Принадлежит: Infineum International Limited

Fouling in a hydrocarbon refining process is reduced by adding to a crude hydrocarbon for a refining process, an additive combination including: 2. The method of where claim 1 , in (A) claim 1 , the polyalkenyl substituent has from 8 to 400 carbon atoms.3. The method of claim 1 , wherein claim 1 , in (A) claim 1 , the polyalkenyl substituent has a number average molecular weight of from 350 to 1000.4. The method of claim 1 , wherein (A) is a succinic acid anhydride.5. The method of claim 4 , wherein (A) is a polyisobutene succinic acid anhydride.6. The method of claim 1 , wherein claim 1 , in (B) claim 1 , the metal is calcium.7. The method of claim 1 , wherein claim 1 , in (B) claim 1 , the hydrocarbyl-substituted hydroxybenzoate is a salicylate.8. The method of claim 1 , wherein claim 1 , in (B) claim 1 , the hydrocarbyl group has from 8 to 400 carbon atoms.9. The method of claim 1 , wherein claim 1 , detergent (B) has a TBN in the range of from about 150 to about 500 mg KOH/g.10. The method of claim 1 , wherein the fouling is particulate-induced fouling.11. A system for refining hydrocarbons comprising:(C) at least one crude hydrocarbon refinery component; and{'claim-ref': {'@idref': 'CLM-00001', 'claim 1'}, '(D) crude hydrocarbon in fluid communication with said at least one refinery component, the crude hydrocarbon containing an additive combination as defined in .'}12. The system of claim 11 , wherein said at least one crude hydrocarbon refinery component is selected from a heat exchanger claim 11 , a furnace claim 11 , a crude preheater claim 11 , a coker preheater claim 11 , a FCC slurry bottom claim 11 , a debutaniser exchanger claim 11 , a debutaniser tower claim 11 , a feed/effluent exchanger claim 11 , a furnace air preheater claim 11 , a flare compressor claim 11 , a steam cracker claim 11 , a steam reformer claim 11 , a distillation column claim 11 , a fractionation column claim 11 , a scrubber claim 11 , a reactor claim 11 , a liquid-jacketed tank ...

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Номер записи: 13
14-01-2016 дата публикации

Compositions and methods for inhibiting fouling in hydrocarbons or petrochemicals

Номер: US20160010006A1
Автор: Alagarsamy Subbiah, Ali FADHEL, Andre C. G. VANHOVE, Anthony Fields, Bryan C. CROM, Nimeshkumar Kantilal Patel, Romit Ghosh
Принадлежит: General Electric Co

Antifoulant compositions and methods are used for inhibiting fouling on structural parts of a system exposed to a fluid hydrocarbon or petrochemical stream. The antifoulant compositions may comprise at least one polyalkylene anhydride ester (“PAAE”) dispersant. Other antifoulant compositions may comprise an alkylphenol sulfide (“APS”).

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Номер записи: 14
03-02-2022 дата публикации

PHOSPHOROUS-FREE OIL SOLUBLE MOLYBDENUM COMPLEXES FOR HIGH TEMPERATURE NAPHTHENIC ACID CORROSION INHIBITION

Номер: US20220033725A1
Автор: Marquez Maria DeJesus, Scholz John Nathan, Thornthwaite Philip Andrew, Zenasni Oussama
Принадлежит:

Disclosed are sulfur-containing molybdenum complexes used in compositions and methods for inhibiting or reducing high temperature corrosion in petroleum refineries. 2. The method of claim 1 , wherein the fluid source is in contact with distillation columns claim 1 , strippers claim 1 , trays claim 1 , or piping.3. The method of claim 1 , wherein the fluid source comprises a liquid hydrocarbon fraction.4. The method of claim 1 , wherein the corrodents comprise naphthenic acid claim 1 , sulfur or combinations thereof.5. The method of claim 1 , wherein the fluid source comprises a TAN of 0.2 to 20 or the fluid source temperature is about 175° C. to 600° C.7. The method of claim 1 , wherein the R claim 1 , R′ comprise each disulfides claim 1 , dithiolates claim 1 , dithiocarbamates claim 1 , dithiocarbonates claim 1 , dithioacids claim 1 , inorganic polysulfides claim 1 , organic polysulfides claim 1 , polymers thereof and mixtures thereof.11. The composition of claim 10 , wherein the composition further comprises one or more claim 10 , asphaltene inhibitors claim 10 , paraffin inhibitors claim 10 , dispersants claim 10 , emulsion breakers claim 10 , or any combination thereof.12. The composition of claim 10 , wherein the fluid source is in contact with distillation columns claim 10 , strippers claim 10 , trays claim 10 , or piping.13. The composition of claim 10 , wherein the fluid source comprises at least a liquid hydrocarbon fraction.14. The composition of claim 10 , wherein the corrodents comprise naphthenic acid claim 10 , sulfur claim 10 , or combinations thereof.15. The composition of claim 10 , wherein the fluid source comprises a TAN of 0.2-20 or the fluid source temperature is 175° C. to 600° C.17. The composition of claim 10 , wherein the R claim 10 , R′ comprise each disulfides claim 10 , dithiolates claim 10 , dithiocarbamates claim 10 , dithiocarbonates claim 10 , dithioacids claim 10 , inorganic polysulfides claim 10 , organic polysulfides claim 10 , ...

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Номер записи: 15
03-02-2022 дата публикации

PHOSPHOROUS-FREE OIL SOLUBLE MOLYBDENUM COMPLEXES AS HIGH TEMPERATURE FOULING INHIBITORS

Номер: US20220033977A1
Автор: Gul Omer, Thornthwaite Philip Andrew, Zenasni Oussama
Принадлежит:

Disclosed are sulfur-containing molybdenum complexes used in compositions and methods for inhibiting or reducing the deposition of foulant on equipment. 2. The method of claim 1 , wherein the introducing is carried out after or during a decoking or cleaning or during a warm up process.3. The method of claim 1 , wherein the introducing is carried out during a hydrocarbon processing.4. The method of claim 1 , wherein the introducing is carried out intermittently or continuously.5. The method of claim 1 , wherein the process equipment comprises coils claim 1 , heat exchangers claim 1 , transfer line exchangers quench coolers claim 1 , furnaces claim 1 , separation columns or fractionators.6. The method of claim 1 , wherein the foulant comprises coke claim 1 , sludge claim 1 , corrosion products claim 1 , polymers claim 1 , and catalyst fines.8. The method of claim 1 , wherein the R or R′ comprise each an alkyl group (linear claim 1 , branched claim 1 , or cyclic) with or without saturation or heteroatoms or both; thiolates claim 1 , sulfides claim 1 , thiocarbamates claim 1 , thiocarbonates claim 1 , thioacids claim 1 , aromatic rings with or without substituents claim 1 , organic polysulfides claim 1 , inorganic polysulfides claim 1 , polymers thereof and combinations thereof.9. The method of claim 8 , wherein the organic polysulfide has the general formula IV:{'br': None, 'sup': 2', '3, 'sub': 'x', 'R—S—R\u2003\u2003Formula IV'}{'sup': 2', '3, 'Wherein Rand Reach represents an oxygen, nitrogen or carbon-containing ligands such as alcohols, alkyl, alkenyl, amides, amines, or aryl groups; and R and R′ can be the same or different.'}11. The method of claim 1 , wherein the sulfur-containing molybdenum complex provides at least 70% inhibition of foulant deposition.14. The composition of claim 12 , wherein the R claim 12 , R′ comprise each an alkyl group (linear claim 12 , branched claim 12 , or cyclic) with or without saturation or heteroatoms or both; thiolates claim 12 ...

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Номер записи: 16
19-01-2017 дата публикации

SCALE COLLECTION AND PREDISTRIBUTION TRAY FOR VESSEL WITH DOWNWARD TWO-PHASE FLOW

Номер: US20170015917A1
Автор: Muller Morten
Принадлежит: MORTEN MULLER LTD. APS

Vapor and liquid flow concurrently down through a vertical vessel. A horizontal scale collection and predistribution tray is located in the vessel to remove solid contaminants and to redistribute the liquid to a fine distribution tray. The scale collection and predistribution tray consists of a tray plate with a scale collection zone where the solid contaminants settle and deposit. In one embodiment, an upstanding permeable wall forms the scale collection zone, and liquid is filtered as it flows through the permeable wall, leaving the solid contaminants trapped upstream from the permeable wall. The predistribution tray has a rim provided with a slotted weir. Liquid from the scale collection zone forms a liquid level in a trough located between the permeable wall and the weir. Due to the uniform liquid level in the trough, liquid flow rates through the slots in the weir are nearly equal. Because of the polygonal shape of the tray, the liquid exits the slots in a direction along lanes defined between distribution units on the fine distribution tray, and the amount of liquid entering the vapor inlets of the distribution units is therefore small. Vapor by-passes the scale collection and pre-distribution tray through the area between the reactor wall and the permeable wall, and through the area between the reactor wall and the weir to the fine distribution tray. The scale collection and predistribution tray protects the fine distribution tray and the catalyst bed from fouling, pre-distributes liquid to the fine distribution tray to minimize level gradients on this tray, and reduces flow velocities to ensure calm flow conditions on the fine distribution tray. 1. A method for removal of solid contaminants from a process stream comprising a vapor and a liquid and for predistribution of the liquid to a fine distribution tray in a catalytic reactor vessel with concurrent downflow of the vapor and the liquid , the method comprising the steps of:providing a scale collection and ...

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Номер записи: 17
21-01-2016 дата публикации

HYDROHALOGENATION OF VINYL TERMINATED POLYMERS AND THEIR FUNCTIONALIZED DERIVATIVES FOR FOULING MITIGATION IN HYDROCARBON REFINING PROCESSES

Номер: US20160017242A1
Автор: Brant Patrick, BRONS Glen Barry, CHASE Clarence, CHENG Hong, Crowther Donna J., NG Man Kit
Принадлежит: EXXONMOBIL RESEARCH AND ENGINEERING COMPANY

A compound useful for reducing fouling in a hydrocarbon refining process is provided. A method for preparing the compound includes hydrohalogenating a polymer having a vinyl chain end to obtain a halogen-containing terminal group, and reacting the terminal group with a polyamine. Methods of using the compound and compositions thereof are also provided.

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Номер записи: 18
21-01-2021 дата публикации

FOULING MITIGATION IN ALKANOLAMINE TREATING SYSTEMS

Номер: US20210016222A1
Автор: Falkiner Robert J., McGARVEY Gordon Bryce, Moreira del Rio Jesus, SLIM David R.
Принадлежит:

Methods for the prevention or mitigation of fouling in amine-treating systems comprising providing circulating aqueous amine solution and a hydrocarbon stream comprising at least one acid gas; and interacting the circulating aqueous amine solution with the hydrocarbon stream comprising the at least one acid gas to remove the acid gas from the hydrocarbon stream and entrain the acid gas into the aqueous amine solution. The circulating aqueous amine solution comprises entrained acid gas comprises foulant precursors; and polysulfide ions are introduced to react with the foulant precursors to decrease the rate of fouling within the circulating aqueous amine solution. 1. A method for the prevention or mitigation of fouling in amine-treating systems comprising:providing circulating aqueous amine solution and a hydrocarbon stream comprising at least one acid gas; and 'wherein the circulating aqueous amine solution comprising entrained acid gas comprises foulant precursors; and', 'interacting the circulating aqueous amine solution with the hydrocarbon stream comprising the at least one acid gas to remove at least a portion of the acid gas from the hydrocarbon stream and entrain the acid gas into the aqueous amine solution;'}introducing polysulfide ions react with the foulant precursors to decrease the rate of fouling within the circulating aqueous amine solution.2. The method of wherein the circulating aqueous amine solution comprises a rich amine circuit and a lean amine circuit; and wherein polysulfide ions are introduced into the rich amine circuit claim 1 , the lean amine circuit claim 1 , or both the rich amine circuit and the lean amine circuit.3. The method of claim 1 , wherein the aqueous amine solution comprises alkanolamines.4. The method of claim 3 , wherein the alkanolamines comprise at least one ethanolamine selected from the group consisting of monoethanolamine (MEA) claim 3 , diethanolamine (DEA) claim 3 , diglycolamine (DGA) claim 3 , di-isopropanolamine ...

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Номер записи: 19
16-01-2020 дата публикации

Mechanical Wall-Treatment Method That Reduces Coke Formation, and Hydrocarbon Treatment Method

Номер: US20200016724A1
Автор: Augustin Christel, Cazottes Sophie, Dupoiron François, Duret Thual Claude, Steyer Philippe, Vaché Nicolas
Принадлежит:

The invention relates to a process for the treatment of a wall made of Fe—Ni—Cr metal alloy of an industrial reactor which reduces the formation of coke on the said wall when it is subjected to operational conditions favourable to coking, the metal alloy comprising, within its structure, carbides, some of which show on the surface. The process comprises a mechanical stage of impact surface treatment, during which a surface of the wall is hammered by projection of particles under conditions suitable for obtaining covering of the carbides initially present at the surface by permanent plastic deformation of the surface, in particular of the chromium carbides. 114.-. (canceled)15. A process for the treatment of a wall made of Fe—Ni—Cr metal alloy of an industrial reactor which reduces the formation of coke on the said wall when it is subjected to operational conditions favourable to coking , the metal alloy comprising , within its structure , carbides , some of which can show on the surface , the process comprising:a mechanical stage of impact surface treatment, during which a surface of the wall is hammered by projection of particles under conditions suitable for obtaining covering of the carbides initially present at the surface by permanent plastic deformation of the surface,the metal alloy containing at least 5% by weight of iron, at least 18% by weight of chromium, at least 25% by weight of nickel and at least 0.05% by weight of carbon.16. The process according to claim 15 , in which the particles used during the mechanical treatment stage are chosen from aluminium oxide particles claim 15 , metal particles claim 15 , beads made of material which is inert under the said operational conditions claim 15 , or nesosilicate particles.17. The process according to claim 15 , in which the particles used during the mechanical treatment stage have a mean diameter of 100 to 500 μm.18. The process according to claim 15 , in which claim 15 , during the mechanical treatment ...

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Номер записи: 20
16-01-2020 дата публикации

METAL CORROSION SUPPRESSING METHOD

Номер: US20200017781A1
Автор: SAITOU Yuusuke, SHIMIZU Masaki, Tsuruta Takuo
Принадлежит: KURARAY CO., LTD.

A method for suppressing metal corrosion attributable to a compound having an SH structure contained in a hydrocarbon, including adding at least one aldehyde selected from the group consisting of a monoaldehyde having 4 or more carbon atoms and a dialdehyde having 3 or more carbon atoms, to the hydrocarbon. 1. A method for suppressing metal corrosion attributable to a compound having an SH structure contained in a hydrocarbon , the method comprising:adding at least one aldehyde selected from the group consisting of a monoaldehyde having 4 or more carbon atoms and a dialdehyde having 3 or more carbon atoms, to the hydrocarbon.2. The method according to claim 1 , wherein the aldehyde is a dialdehyde having 3 or more carbon atoms.3. The method according to claim 1 , wherein the aldehyde is at least one selected from the group consisting of 3-methylglutaraldehyde claim 1 , 1 claim 1 ,9-nonanedial claim 1 , and 2-methyl-1 claim 1 ,8-octanedial.4. The method according to claim 1 , wherein the hydrocarbon is at least one selected from the group consisting of natural gas claim 1 , liquefied natural gas claim 1 , liquefied petroleum gas claim 1 , sour gas claim 1 , dry gas claim 1 , wet gas claim 1 , oilfield gas claim 1 , associated gas claim 1 , tail gas claim 1 , dimethyl ether claim 1 , crude oil claim 1 , naphtha claim 1 , heavy aromatic naphtha claim 1 , gasoline claim 1 , kerosene claim 1 , diesel oil claim 1 , gas oil claim 1 , lubricant oil claim 1 , heavy oil claim 1 , A-type fuel oil claim 1 , B-type fuel oil claim 1 , C-type fuel oil claim 1 , jet fuel oil claim 1 , FCC slurry claim 1 , asphalt claim 1 , oil field condensate claim 1 , bitumen claim 1 , extra heavy oil claim 1 , tar claim 1 , gas to liquid claim 1 , coal to liquid claim 1 , asphaltene claim 1 , aromatic hydrocarbon claim 1 , alkylate claim 1 , base oil claim 1 , kerogen claim 1 , coke claim 1 , black oil claim 1 , synthetic crude oil claim 1 , reformulated gasoline claim 1 , isomerized gasoline ...

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Номер записи: 21
28-01-2016 дата публикации

Method of Reducing Corrosion and Corrosion Byproduct Deposition in a Crude Unit

Номер: US20160024395A1
Автор: Ferguson Sam, Scattergood Glenn L.
Принадлежит: NALCO COMPANY

A method of optimizing system parameters in a crude unit to reduce corrosion and corrosion byproduct deposition in the crude unit is disclosed and claimed. The method includes measuring or predicting properties associated with the system parameters and using an automated controller to analyze the properties to cause adjustments in the chemical program to optimize the system parameters. Adjusting the system parameters effectively controls corrosion in the crude unit by reducing the corrosiveness of a fluid in the process stream and/or by protecting the system from a potentially corrosive substance. System parameter sensing probes are arranged at one or more locations in the process stream to allow accurate monitoring of the system parameters in the crude unit. 119-. (canceled)20. A method of optimizing a system parameter in a process stream of a crude unit , the method comprising:(a) introducing a challenging crude oil into a crude unit that previously contained a different kind of crude oil, the properties of the challenging crude differing such from the previous crude oil that it disrupts the steady state of the unit including causing a corrosion inducing spike in chloride concentration,(b) measuring and/or predicting a property associated with the system parameter at one or more points in the crude unit;(c) determining an optimum range associated with the measured and/or predicted property;(d) if the measured and/or predicted property is outside of the optimum range associated with that property, causing a change in an influx of a composition into the process stream, the composition capable of adjusting the property associated with the system parameter in a manner to bring the measured and/or predicted property within said optimum range; provided that adjustments are limited to no more than one per 30 minutes and if there are either four overall adjustments or the adjustment results in a change of at least 50% of added composition then further influx of ...

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Номер записи: 22
26-01-2017 дата публикации

METHOD AND SYSTEM FOR ANALYSING A BLEND OF TWO OR MORE HYDROCARBON FEED STREAMS

Номер: US20170023485A1
Автор: STUBBINS Frederick J., Wade John, WINSTONE Paul
Принадлежит: INTERTEK GROUP PLC

The invention relates to a method for analysing a blend of two or more hydrocarbon feed streams such as crude oils. These crude oils are blended in a facility such as a refinery. The method assesses the compatibility of a hydrocarbon feed in a blend to calculate the blend stability such that organic deposition is minimised. The method uses all of a plurality of hydrocarbon feeds to be blended for analysis. The method either selects a neat hydrocarbon feed, from a plurality of the hydrocarbon feeds included in a blend, as a titrant, wherein the or each other hydrocarbon in the hydrocarbon feed are used to make a pseudo-blend and titrating the pseudo-blend with said selected neat hydrocarbon feed for a plurality of different blend ratios. Alternatively the method involves preparing a reference hydrocarbon and making a blend from the plurality of hydrocarbon feeds and titrating the blend with the reference hydrocarbon. Measurements associated with the change in characteristics of the titrated blend are made and data recorded. The method then calculates, using said data, the stability of the blend. 1. A method for analysing a blend of two or more hydrocarbon feed streams such as crude oils for processing in a blending facility such as a refinery for assessing the compatibility of a hydrocarbon feed in a blend to calculate the blend stability for assessing organic deposition from said blend , the method including: (i) selecting a neat hydrocarbon feed, from a plurality of the hydrocarbon feeds included in a blend, as a titrant, wherein the or each other hydrocarbon in the hydrocarbon feed are used to make a pseudo-blend, or', '(ii) preparing a reference hydrocarbon and making a blend from the plurality of hydrocarbon feeds;, 'using all of a plurality of hydrocarbon feeds to be blended for analysis and either'}titrating the pseudo-blend with said selected neat hydrocarbon feed for a plurality of different blend ratios, or titrating the blend with the reference hydrocarbon ...

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Номер записи: 23
10-02-2022 дата публикации

MEANS AND METHODS FOR MANAGING AMMONIA, AMINE AND NORMAL SALT FOULING IN OIL PRODUCTION AND REFINING

Номер: US20220041941A1
Автор: Bosch Ronald Oliver, Crow Charles Richard, JR. Russell Cody, Saulnier Richard Wayne, Strong
Принадлежит:

Methods for use in treating hydrocarbon streams are provided. The methods of the present disclosure include; introducing one or more alcohols into a hydrocarbon stream that includes one or more hydrolyzable chloride compounds; allowing the one or more alcohols to interact with, the one or more hydrolyzable chloride compounds; and increasing: one of a solubility value or a dispersancy value of at least a portion of the hydrolyzable chloride compounds in the hydrocarbon steam. 1. A method comprising:introducing one or more alcohols into a hydrocarbon stream that comprises one or more hydrolyzable chloride compounds;allowing the one or more alcohols to interact with the one or more hydrolyzable chloride compounds; andincreasing one of a solubility value or a dispersancy value of at least a portion of the hydrolyzable chloride compounds in the hydrocarbon steam.2. The method of claim 1 , wherein the one or more alcohols are selected from the group consisting of: methanol claim 1 , ethanol claim 1 , propanol claim 1 , butanol claim 1 , pentanol claim 1 , ethylene glycol claim 1 , propylene glycol claim 1 , glycerol claim 1 , erythritol claim 1 , xylitol claim 1 , sorbitol claim 1 , volemitol claim 1 , inositol claim 1 , any oligomer thereof claim 1 , any polymer thereof claim 1 , and any combination thereof.3. The method of claim 1 , wherein the one or more alcohols comprises an ethylene glycol or one or more oligomers or polymers thereof.4. The method of further comprising introducing one or more salt control additives into the hydrocarbon stream.5. The method of claim 4 , wherein the one or more salt control additives is selected from the group consisting of: a choline salt claim 4 , any analogue thereof claim 4 , any polymer thereof claim 4 , and any combination thereof.6. The method of claim 4 , wherein the one or more salt control additives is selected from the group consisting of: a quaternized ammonia salt claim 4 , a quaternized amine claim 4 , any analogue ...

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Номер записи: 24
28-01-2021 дата публикации

Process for the Positioning of a Corrosion-Resistant Coating on a Wall of an Item of Equipment of a FCC Unit

Номер: US20210023521A1
Автор: Sebastien Decker
Принадлежит: Total Raffinage Chimie SAS

The invention relates to a process for the positioning of a corrosion-resistant coating on an internal or external metal wall ( 20 ) of a fluid catalytic cracking unit chamber, comprising: (i) the shaping of a metal anchoring structure ( 10 ) formed from a plurality of strips ( 12 ) assembled in pairs by joining assembly portions ( 121, 122 ) so as to form a plurality of cells ( 14 ), the anchoring structure comprising a plurality of fastening tabs ( 16 ) integral with strip portions other than assembly portions, (ii) the fastening of said anchoring structure ( 10 ) by welding the free edge ( 18 ) of a part at least of the fastening tabs to the metal wall ( 20 ), defining a space between a longitudinal edge ( 12 b ) of an anchoring structure and the metal wall, (iii) the insertion of a composite material into the cells ( 14 ) from the metal wall ( 20 ) and at least up to the upper longitudinal edge ( 12 a ) of each strip.

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Номер записи: 25
02-02-2017 дата публикации

Monolayer coated cooperating surfaces, method of treating cooperating surfaces, and method of installing cooperating surfaces into crude oil service operation

Номер: US20170029725A1
Автор: Andrew Timothy Marzec, Brian Keith Brashear, Sean Eric Drees
Принадлежит: Electrolab Inc

A device having cooperating surfaces, method of treating cooperating surfaces of a device, and method of installing device having cooperating surfaces, wherein the device may include a first cooperating surface and a second cooperating surface, and wherein the first and second surfaces form cooperating surfaces, and wherein at least one of the surfaces comprises a monolayer. The method of treating cooperating surfaces includes applying a coat of a monolayer composition to at least one of said cleaned and dried surfaces. The method of installing may include installing said device into a section of a crude oil service operation.

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Номер записи: 26
02-02-2017 дата публикации

MONOLAYER METHOD FOR PRECIPITATING SOLIDS, FOR TREATING A LIQUID CONTAINING CONTAMINANTS, FOR TREATING A SURFACE RESIDING IN A LIQUID CONTAINING CONTAMINANTS

Номер: US20170029726A1
Автор: Brashear Brian Keith, DREES SEAN ERIC, MARZEC ANDREW TIMOTHY
Принадлежит: ELECTROLAB, INC

Methods for precipitating solids comprising asphaltenes and/or paraffins that may include precipitating the solid and contacting the solid with a surface comprising a monolayer coating or alternatively may include precipitating the solid in the presence of such a surface. The method for treating a liquid containing contaminants comprising asphaltenes and/or paraffins may include inserting into the liquid, a surface as described above, or further coating surfaces within the liquid with a monolayer coating. 1. A method for handling precipitating solids comprising at least one selected from the group consisting of paraffin and asphaltene , comprising the steps of:precipitating the solid; and,contacting a surface with the solid, wherein the surface comprises a monolayer.2. The method of claim 1 , wherein the solids reside in crude oil claim 1 , and the contacting occurs in the presence of crude oil.3. The method of claim 1 , wherein the surface further comprises at least one of a tracer additive claim 1 , corrosion inhibitor claim 1 , or anti-static additive.4. A method for handling solids comprising at least one selected from the group consisting of paraffin and asphaltene claim 1 , comprising the step of:contacting a surface with the solid, wherein the surface comprises a monolayer.5. The method of claim 4 , wherein the solids reside in crude oil claim 4 , and the contacting occurs in the presence of crude oil.6. The method of claim 4 , wherein the surface further comprises at least one of a tracer additive claim 4 , corrosion inhibitor claim 4 , or anti-static additive.7. A method for precipitating solids comprising at least one selected from the group consisting of paraffin and asphaltene claim 4 , the method comprising the step of:precipitating the solids in the presence of a surface comprising a monolayer.8. The method of claim 7 , wherein the precipitating occurs in the presence of crude oil.9. The method of claim 7 , wherein the surface further comprises at ...

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Номер записи: 27
02-02-2017 дата публикации

BONDED LAYER METHOD FOR PRECIPITATING SOLIDS, FOR TREATING A LIQUID CONTAINING CONTAMINANTS, FOR TREATING A SURFACE RESIDING IN A LIQUID CONTAINING CONTAMINANTS

Номер: US20170029727A1
Автор: Brashear Brian Keith, DREES SEAN ERIC, MARZEC ANDREW TIMOTHY
Принадлежит: ELECTROLAB, INC

Methods for precipitating solids comprising asphaltenes and/or paraffins that may include precipitating the solid and contacting the solid with a surface comprising a bonded layer coating or alternatively may include precipitating the solid in the presence of such a surface, wherein the bonded layer is a molecularly bonded layer or a covalently bonded layer. The method for treating a liquid containing contaminants comprising asphaltenes and/or paraffins may include inserting into the liquid, a surface as described above, or further coating surfaces within the liquid with a bonded layer coating. 1. A method for handling precipitating solids comprising at least one selected from the group consisting of paraffin and asphaltene , comprising the steps of:precipitating the solid; and,contacting a surface with the solid, wherein the surface comprises a bonded layer,wherein the bonded layer is a molecularly bonded layer or a covalently bonded layer.2. The method of claim 1 , wherein the solids reside in crude oil claim 1 , and the contacting occurs in the presence of crude oil.3. The method of claim 1 , wherein the surface further comprises at least one of a tracer additive claim 1 , corrosion inhibitor claim 1 , or anti-static additive.4. A method for handling solids comprising at least one selected from the group consisting of paraffin and asphaltene claim 1 , comprising the step of:contacting a surface with the solid, wherein the surface comprises a bonded layer,wherein the bonded layer is a molecularly bonded layer or a covalently bonded layer.5. The method of claim 4 , wherein the solids reside in crude oil claim 4 , and the contacting occurs in the presence of crude oil.6. The method of claim 4 , wherein the surface further comprises at least one of a tracer additive claim 4 , corrosion inhibitor claim 4 , or anti-static additive.7. A method for precipitating solids comprising at least one selected from the group consisting of paraffin and asphaltene claim 4 , the ...

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Номер записи: 28
02-02-2017 дата публикации

SAMP TREATMENT METHOD FOR A DEVICE UTILIZED IN A CRUDE OIL SERVICE OPERATION, AND METHOD OF INSTALLING SAID DEVICE

Номер: US20170029728A1
Автор: Brashear Brian Keith, DREES SEAN ERIC, MARZEC ANDREW TIMOTHY
Принадлежит: ELECTROLAB, INC.

A method for installing a device into a crude oil service operation, the method may include installing the device into a section of the crude oil service operation, wherein the device comprises a surface comprising a Self-Assembled Monolayer of Phosphonate (SAMP) coating, and may also include contacting the surface with the contaminant, wherein the contaminant is selected from the group consisting of paraffins and asphaltenes. Various systems include one having a liquid environment of paraffins and asphaltene, and a surface residing within the environment comprising a Self-Assembled Monolayer of Phosphonate (SAMP) composition. Systems also include pipelines and vessels having an internal surface therein comprising a Self-Assembled Monolayer of Phosphonate (SAMP) composition, and with hydrocarbon liquids present in the pipeline or vessel. 1. A method for treating a device utilized in a crude oil service operation , wherein the device comprises at least one surface , the method comprising the steps of:Cleaning the surface to remove surface contamination;Drying the cleaned surface of the device;Applying a coat of a Self-Assembled Monolayer of Phosphonate (SAMP) composition to the clean and dried surfaces of said device to form a treated deviceInstalling said treated device into a section of a crude oil service operation; and,Contacting the surface with a contaminant, wherein the contaminant is selected from the group consisting of paraffins and asphaltenes.2. The method of claim 1 , wherein during the contacting step claim 1 , crude oil is present.3. The method of claim 1 , wherein during the installing step claim 1 , crude oil is present.4. The method of claim 1 , wherein the composition further comprises at least one of a tracer additive claim 1 , corrosion inhibitor claim 1 , or anti-static additive.5. A method for installing a device into a crude oil service operation claim 1 , the method comprising the step of:Installing the device into a section of the crude oil ...

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Номер записи: 29
02-02-2017 дата публикации

MONOLAYER TREATMENT METHOD FOR A DEVICE UTILIZED IN A CRUDE OIL SERVICE OPERATION, AND METHOD OF INSTALLING SAID DEVICE

Номер: US20170029729A1
Автор: Brashear Brian Keith, DREES SEAN ERIC, MARZEC ANDREW TIMOTHY
Принадлежит: ELECTROLAB, INC.

A method for installing a device into a crude oil service operation, the method may include installing the device into a section of the crude oil service operation, wherein the device comprises a surface comprising a monolayer coating, and may also include contacting the surface with the contaminant, wherein the contaminant is selected from the group consisting of paraffins and asphaltenes. Various systems include one having a liquid environment of paraffins and asphaltene, and a surface residing within the environment comprising a monolayer composition. Systems also include pipelines and vessels having an internal surface therein comprising a monolayer composition, and with hydrocarbon liquids present in the pipeline or vessel. 1. A method for treating a device utilized in a crude oil service operation , wherein the device comprises at least one surface , the method comprising the steps of:cleaning the surface to remove surface contamination;drying the cleaned surface of the device;applying a coat of a monolayer composition to the clean and dried surfaces of said device to form a treated device installing said treated device into a section of a crude oil service operation; and,contacting the surface with a contaminant, wherein the contaminant is selected from the group consisting of paraffins and asphaltenes.2. The method of claim 1 , wherein during the contacting step claim 1 , crude oil is present.3. The method of claim 1 , wherein during the installing step claim 1 , crude oil is present.4. The method of claim 1 , wherein the composition further comprises at least one of a tracer additive claim 1 , corrosion inhibitor claim 1 , or anti-static additive.5. A method for installing a device into a crude oil service operation claim 1 , the method comprising the step of:installing the device into a section of the crude oil service operation, wherein the device comprises a surface comprising a monolayer coating; and,contacting the surface with the contaminant, wherein ...

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Номер записи: 30
04-02-2016 дата публикации

Process for Introducing Fine and Coarse Additives for Hydroconversion of Heavy Hydrocarbons

Номер: US20160032198A1
Автор: Schleiffer Andreas, SUBRAMANIAN Anand
Принадлежит:

A process for slurry-phase hydrocracking of a heavy hydrocarbon feedstock in a reactor, such as an upflow bubble column reactor, includes separately introducing additive in two size ranges into the feedstock. A fine size particle additive is introduced upstream of a coarse size particle additive. 1. A process for slurry-phase hydrocracking of a heavy hydrocarbon feedstock in a slurry phase hydrocracking reactor , the process comprising:introducing a first additive to the feedstock upstream of a pre-heat exchanger to form a fines-loaded feedstock, the additive comprising fines particles having a particle size distribution less than 500 microns,separately introducing a second additive to the fines-loaded feedstock downstream of a feed charge pump and upstream of the slurry phase hydrocracking reactor, the second additive comprising coarse particles having a median particle size between 400 microns and 2,000 microns; andremoving reaction products from the slurry phase hydrocracking reactor.2. The process of claim 1 , wherein the slurry phase hydrocracking reactor is an upflow bubble column reactor.3. The process of claim 1 , wherein the slurry phase hydrocracking reactor is a circulating ebulated bed reactor.4. The process of claim 1 , wherein the heavy hydrocarbon feedstock comprises of a mineral oil claim 1 , synthetic oil claim 1 , heavy oil claim 1 , residual oil claim 1 , waste oil claim 1 , shale oil claim 1 , used oil claim 1 , tar sand oil claim 1 , coal oil claim 1 , coal tar claim 1 , vacuum residue claim 1 , atmospheric residue claim 1 , deasphalted bottoms claim 1 , comminuted coal claim 1 , biomass-derived materials claim 1 , and mixtures thereof.5. The process of claim 1 , wherein the heavy hydrocarbon feedstock comprises vacuum residue.6. The process of claim 1 , wherein the first additive is introduced to the feedstock in a feed mixing vessel.7. The process of claim 1 , wherein the first additive is introduced to the feedstock downstream of the feed ...

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Номер записи: 31
02-02-2017 дата публикации

CORROSION INHIBITOR DERIVED FROM VEGETABLE OILS AND IT'S PROCESS OF OBTAINING

Номер: US20170029960A1
Автор: BENITEZ AGUILAR Jose Luis Rodolfo, ESTRADA MARTINEZ Arquimedes, NAVARRO ORDONEZ Nancy, TOBON CERVANTES Amalia
Принадлежит:

The present invention is directed to a formulation of corrosion inhibitors for corrosion control of low carbon steel piping, carrying different fuels products, obtained in refineries or petrochemical processes. The composition comprises active imidazoline inhibitors derived from vegetable oil selected from the group consisting of sunflower, canola, soybean, safflower, corn and mixtures thereof that are reacted with a polyalkylated polyamines such as diethylenetriamines (DETA), triethylenetetramine (TETA) and tetraethylenepentamine (TEPA). The imidazoline is reacted with 1 to 3 moles of a carboxylic acid having 2 to 6 carbon atoms. The product obtained is formulated with 50 to 60% weight of an aromatic solvent and 10 to 20 wt % of an alcohol. The compositions were evaluated in sour environments under the NACE TM0172 and ASTM G 185 method, and both, sour and sweet environments in the NACE ID182 method, so they are fit to pass the tests as indicated by the NRF-005-PEMEX-2009 standard for application in pipelines. 1. A corrosion inhibitor composition for low carbon steel pipelines for the transportation of sour or sweet hydrocarbon streams , said composition comprising 30 to 40% of an active carboxy-imidazoline corrosion inhibitor derived from vegetable oil selected from the group consisting of sunflower , canola , safflower , and canola/Sunflower , 5 to 10 wt.% glycerin and 50 to 60 wt.% of an aromatic solvent and 10-20 wt.% of an alcohol.3. The corrosion inhibitor composition in accordance with claim 2 , wherein the carboxylic acid is acrylic acid.5. A method of producing the inhibitor composition of claim 1 , wherein said method comprised a first step of producing an imidazoline precursor claim 1 , and a second step of modifying the imidazoline precursor to obtain the carboxy-imidazoline active component.6. The method in accordance with claim 5 , wherein the limidazoline precursors are obtained from sunflower claim 5 , canola claim 5 , soybean claim 5 , safflower ...

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Номер записи: 32
05-02-2015 дата публикации

H2S SCAVENGERS WITH SYNERGISTIC CORROSION INHIBITION

Номер: US20150034319A1
Автор: Taylor Grahame N.
Принадлежит: BAKER HUGHES INCORPORATED

Triazine hydrogen sulfide (HS) scavengers consume HS and form dithiazines by-products which are corrosion inhibitors. Triazine HS scavengers may be formulated with other corrosion inhibitors and used in HS-containing fluids so that the dithiazine by-products may together with the at least one additional corrosion inhibitor form give synergistically better inhibiting of corrosion of iron and/or iron alloys in contact with the fluid to an extent greater than additive of the corrosion inhibition of the dithiazine and the corrosion inhibition of the at least one additional corrosion inhibitor, taken separately. The dithiazine may have the formula: 1. A method for scavenging hydrogen sulfide (HS) from and providing corrosion inhibition to a fluid in contact with iron and/or iron alloys comprising:{'sub': '2', 'claim-text': [{'sub': '2', 'a triazine that reacts with HS to form a dithiazine capable of and in an amount effective for inhibiting corrosion in the fluid, and'}, 'at least one additional corrosion inhibitor capable of and in an amount effective for inhibiting corrosion in the fluid;, 'introducing to a HS-containing fluid in any order{'sub': '2', 'at least partially reacting the triazine with HS forming the dithiazine;'}contacting the dithiazine with the at least one additional corrosion inhibitor, andinhibiting corrosion of iron and/or iron alloys in contact with the fluid to an extent greater than additive of the corrosion inhibition of the dithiazine and the corrosion inhibition of the at least one additional corrosion inhibitor, taken separately.2. The method of further comprising introducing the fluid into a wellbore.4. The method of where R is —R—OH claim 1 , where Ris an alkylene group.5. The method of where Ris an alkylene group of C-C.6. The method of where the at least one additional corrosion inhibitor is selected from the group consisting of:(a) an alkyl, alkylaryl or arylamine quaternary salt with an alkyl or alkylaryl halide;(b) a mono or polycyclic ...

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Номер записи: 33
04-02-2021 дата публикации

METHOD OF DECONTAMINATING A HYDROCARBON FLUID USING GAMMA RADIATION

Номер: US20210030903A1
Автор: Smith Casey Joe, Smith Davis
Принадлежит:

In an aspect, a method of decontaminating a hydrocarbon fluid comprises irradiating the hydrocarbon fluid in a storage tank with a gamma radiation to maintain or reduce an amount of a microorganism in the storage tank; wherein a source of the gamma radiation is located within and/or proximal to the storage tank. In another aspect, a method of reducing an amount of a biocorrosion comprises irradiating the biocorrosion located on a surface of a device in contact with a hydrocarbon fluid with a gamma radiation; wherein a source of the gamma radiation is located within and/or proximal to the device. 1. A method of decontaminating a hydrocarbon fluid comprising:irradiating the hydrocarbon fluid in a storage tank with a gamma radiation to maintain or reduce an amount of a microorganism in the storage tank;wherein a source of the gamma radiation is located within and/or proximal to the storage tank.2. The method of claim 1 , further comprising mixing the hydrocarbon fluid in the storage tank.3. The method of claim 1 , wherein the irradiating comprises irradiating an inner surface of the storage tank to reduce the amount of biocorrosion on the inner surface or to prevent the biocorrosion from forming on the inner surface.4. The method of claim 1 , wherein the irradiating comprises irradiating a head space of the storage tank to reduce the amount of biocorrosion in the head space or to prevent the biocorrosion in the head space.5. The method of claim 1 , wherein at least 10 volume percent of the storage tank is located underground.6. The method of claim 5 , wherein 100 volume percent of the storage tank is located underground such that the gamma radiation does not reach a ground-level surface.7. The method of claim 1 , wherein the storage tank has an inner volume of greater than or equal to 20 meters cubed; and/or wherein the storage tank can hold 55 to 160 claim 1 ,000 liters of the hydrocarbon fluid.8. The method of claim 1 , wherein the storage tank comprises at least one ...

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Номер записи: 34
04-02-2021 дата публикации

Oil soluble molybdenum complexes for inhibiting high temperature corrosion and related applications in petroleum refineries

Номер: US20210032758A1
Автор: Janelle Pennington, Oussama ZENASNI, Philip Andrew Thornthwaite, Ramon Colorado, Jr.
Принадлежит: ECOLAB USA INC

Disclosed are molybdenum-containing complexes used in compositions and methods for inhibiting or reducing high temperature corrosion in petroleum refineries.

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Номер записи: 35
11-02-2016 дата публикации

Functionalized polymers containing polyamine succinimide for antifouling in hydrocarbon refining processes

Номер: US20160039753A1
Автор: Clarence CHASE, David T. Ferrughelli, Donna J. Crowther, Edward Andrew Lemon, Emmanuel ULYSSE, Geoffrey Marshall KEISER, Glen Barry Brons, Hong Cheng, Man Kit Ng, Mohsen S. Yeganeh, Patrick Brant, Timothy Andrew Barckholtz
Принадлежит: ExxonMobil Research and Engineering Co

A multipurpose chemical additives (MPC) is disclosed to mitigate fouling in hydrocarbon refinery processes, such as in a heat exchanger. A method for reducing fouling of a hydrocarbon is also disclosed that includes (i) providing a crude hydrocarbon for a refining process; and (ii) adding an additive to the crude hydrocarbon.

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Номер записи: 36
11-02-2016 дата публикации

Rejuvenation of Biopyrolysis Oil Hydroprocessing Reactors

Номер: US20160040077A1
Автор: Bauer Lorenz, Lee Michael, Smith Dave, Zhang Changan
Принадлежит:

A process and system for hydroprocessing biopyrolysis oils is provided and includes the rejuvenation of an at least partially flow constricted biopyrolysis oil hydroprocessing reactor(s) by flushing with a flushing agent at reduced temperatures. 1. A process comprising the steps of:(a) providing an at least partially flow constricted biopyrolysis oil hydroprocessing reactor comprising a hydroprocessing catalyst and flow constricting deposits; and(b) flushing the at least partially flow constricted biopyrolysis oil hydroprocessing reactor with a flushing agent resulting in a rejuvenated biopyrolysis oil hydroprocessing reactor comprising less flow constricting deposits as compared to the at least partially flow constricted biopyrolysis oil hydroprocessing reactor.2. The process of wherein the at least partially flow constricted biopyrolysis oil hydroprocessing reactor has an elevated pressure drop in the range of from about 15 psig to about 100 psig claim 1 , and the rejuvenated biopyrolysis oil hydroprocessing reactor has a lower pressure drop in the range of from about 5 psig to about 15 psig.3. The process of wherein the flow constricting deposits comprise a component selected from the group consisting of: high boiling components of a biopyroloysis oil feedstream claim 1 , high boiling components of a partially reacted product of the biopyrolysis oil feedstream claim 1 , char claim 1 , catalyst fines claim 1 , and combinations thereof.4. The process of wherein the flushing agent is selected from the group consisting of hydrogen gas claim 1 , a polar solvent claim 1 , a biopyrolysis oil claim 1 , and combinations thereof.5. The process of wherein the flushing of step (b) is performed at a temperature less than about 200° F.6. The process of wherein the flushing agent comprises the polar solvent.7. The process of wherein the polar solvent is a polar aprotic solvent.8. The process of wherein the polar solvent is a polar protic solvent.9. The process of wherein the ...

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Номер записи: 37
09-02-2017 дата публикации

METHOD, APPARATUS AND CHEMICAL PRODUCTS FOR TREATING PETROLEUM EQUIPMENT

Номер: US20170037327A1
Автор: FERRARA Marcello
Принадлежит:

The present invention provides a method, an apparatus and chemical products for treating petroleum equipment wherein a fluid is flowing, preferably of the hydrocarbon type, and wherein treating is performed by establishing a closed or semi-closed flow circulation loop, during the normal production operations of the equipment. The treatment can refer to the cleaning of equipment, to yield improvement as compared to normal run conditions and/or to a reduction of coke formation and/or to coke removal on catalysts. 1. A method for treating a petroleum plant or equipment of the petroleum plant during a running of the petroleum plant , comprising:maintaining, during a treatment period, the petroleum plant under a production operating condition, typical of the plant itself, which includes providing fresh feed to the petroleum plant;while maintaining the petroleum plant under the production operating condition, there is carried out one or both of a) and b);a) introducing in the petroleum plant, during the treatment period, a hydrocarbon-based treatment fluid;b) varying an established feed rate, present at initiation of the treatment of the petroleum plant or equipment of the petroleum plant, which established feed rate ranges from a maximum operation rate for the petroleum plant, which is inclusive of a design rate for the petroleum plant, to a minimum operation rate which is set at a level for satisfying a minimum production operating state in the petroleum plant;wherein said introduction of a hydrocarbon-based treatment fluid and/or said variation to the treatment feed rate generates an additional source or sources for distillation with respect to the amount provided by the established rate; anddistilling said additional source or sources for distillation for the purpose of plant treatment.2. The method of wherein the additional source or sources of distillate generated by the variation to the treatment feed rate is fed into the current fresh feed of the plant as the ...

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Номер записи: 38
12-02-2015 дата публикации

Hydrotreating process and apparatus relating thereto

Номер: US20150041365A1
Автор: David M. Bowman, Richard K. Hoehn, Soumendra Mohan Banerjee, Xin X. Zhu
Принадлежит: UOP LLC

One exemplary embodiment can be a process for treating a hydroprocessing fraction. The process can include obtaining a bottom stream from a fractionation zone, and passing at least a portion of the bottom stream to a film generating evaporator zone for separating a first stream containing less heavy polynuclear aromatic compounds than a second stream.

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Номер записи: 39
13-02-2020 дата публикации

SYSTEMS AND METHODS FOR ON-LINE PIGGING AND SPALLING OF COKER FURNACE OUTLETS

Номер: US20200048558A1
Автор: Alexander Scott, DOERKSEN Brian, Gonzalez Jorge, HENIFORD Rick, VON BRECHT Richard, Ward John
Принадлежит: Bechtel Hydrocarbon Technology Solutions, Inc.

Systems and methods for safe on-line pigging decoking of a coker furnace tubes and which also permits on-line spalling operations. 1. A method for on-line pigging in a tube coil for a furnace in a delayed coking system , which comprises:terminating a process fluid supply flow to the furnace;introducing high pressurized steam from a first pressurized steam source through the tube coil and a main line, and from a second pressurized steam source through a second line connected to the main line;isolating a vent, in fluid communication with the second line, from the main line by introducing high pressurized steam from a third pressurized steam source through the second line to maintain a constant pressure against one side of first and second closed valves positioned in fluid communication with the vent between the vent and the main line while introducing the high pressurized steam from the first pressurized steam source and the second pressurized steam source;terminating the introduction of the high pressurized steam from the first pressurized steam source, the second pressurized steam source and the third pressurized steam source;isolating a drum input line, in fluid communication with the main line, from a portion of the main line by introducing high pressurized steam from a fourth pressurized steam source through a third line connected to the main line to maintain a constant pressure against one side of third, fourth and fifth valves in fluid communication with the drum input line;disconnecting the tube coil from the main line and the first pressurized steam source;connecting the tube coil to a pigging unit after the main line reaches atmospheric pressure; andintroducing water from a water source to the pigging unit for driving a pig through the tube coil.2. The method of claim 1 , further comprising:supplying steam to the tube coil and to a closed blowdown system header until the tube coil of the furnace reaches at least about 400° F. and not more than about 700° F. ...

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Номер записи: 40
23-02-2017 дата публикации

Design Development and Implementation of Analyzer Based Control System and Algorithm

Номер: US20170051215A1
Автор: Ferguson Sam, Hilton Nigel P., Scattergood Glenn L., Wang Jin
Принадлежит: NALCO COMPANY

A method of correcting measurements of a chemical sensor used in an industrial facility. The method involves correcting for errors known to occur in the steady state and the dynamic state for specifically recognized situations. This method allows for correcting errors that occur due to deadtime, false zero measurements, and non-linear disturbances. The method combines automated measurement techniques and human know how to progressively learn and refine the accuracy of the corrections. 111-. (canceled)12. A method of controlling corrosion rate of a crude oil refinery process comprising:measuring copper concentration of the crude oil refinery process to establish an initial corrosion rate of the crude oil refinery process;measuring pH of the crude oil refinery process;measuring chloride concentration of the crude oil refinery process;altering the initial corrosion rate of the crude oil refinery process according to the measured pH and the measured chloride concentration and correcting for dynamic state error, thereby determining an altered corrosion rate;comparing the altered corrosion rate to a pre-determined range of acceptable values;if the altered corrosion rate is outside of the pre-determined range of acceptable values, performing a remedial measure to change the altered corrosion rate to a value within the range of acceptable values; andrepeating the steps.13. The method of claim 12 , wherein the remedial measure comprises adding to the crude oil refinery process a chemical selected from the group consisting of: a neutralizer claim 12 , a caustic agent claim 12 , a filming inhibitor claim 12 , and combinations thereof.14. The method of claim 12 , wherein the remedial measure comprises adding a neutralizer to the crude oil refinery process.15. The method of claim 14 , wherein the neutralizer is selected from the group consisting of: 3-methoxypropylamine claim 14 , monoethanolamine claim 14 , N claim 14 ,N-dimethylaminoethanol claim 14 , methoxyisopropylamine ...

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Номер записи: 41
03-03-2016 дата публикации

HYDROHALOGENATION OF VINYL TERMINATED POLYMERS AND THEIR FUNCTIONALIZED DERIVATIVES FOR FOULING MITIGATION IN HYDROCARBON REFINING PROCESSES

Номер: US20160060551A1
Автор: Brant Patrick, BRONS Glen Barry, CHASE Clarence, CHENG Hong, Crowther Donna J., NG Man Kit
Принадлежит: EXXONMOBIL RESEARCH AND ENGINEERING COMPANY

A compound useful for reducing fouling in a hydrocarbon refining process is provided. A method for preparing the compound includes hydrohalogenating a polymer having a vinyl chain end to obtain a halogen-containing terminal group, and reacting the terminal group with a polyamine. Methods of using the compound and compositions thereof are also provided. 117.-. (canceled)19. The method of claim 18 , wherein Rcomprises polypropylene.20. The method of claim 19 , wherein the polypropylene is atactic polypropylene claim 19 , isotactic polypropylene claim 19 , or syndiotactic polypropylene.21. The method of claim 19 , wherein the polypropylene is amorphous.22. The method of claim 19 , wherein the polypropylene includes isotactic or syndiotactic crystallizable units.23. The method of claim 19 , wherein the polypropylene includes meso diads constituting from about 30% to about 99.5% of the total diads of the polypropylene.24. The method of claim 18 , wherein the molar ratio of R:polyamine is between about 5:1 and about 1:1.25. The method of claim 18 , wherein Rhas a number-averaged molecular weight of from about 300 to about 30000 g/mol.26. The method of claim 25 , wherein Rhas a number-averaged molecular weight of from about 500 to about 5000 g/mol.27. The method of claim 18 , wherein Rcomprises polyethylene.28. The method of claim 18 , wherein Rcomprises poly(ethylene-co-propylene).29. The method of claim 18 , wherein Rcomprises from about 10 mole % to about 90 mole % of ethylene units and from about 90 mole % to about 10 mole % propylene units.30. The method of claim 29 , wherein Rcomprises from about 20 mole % to about 50 mole % of ethylene units.31. The method of claim 18 , wherein Rcomprises poly(higher alpha-olefin) claim 18 , the higher alpha-olefin including two or more carbon atoms on each side chain.32. The method of claim 18 , wherein Rcomprises poly(propylene-co-higher alpha-olefin) claim 18 , the higher alpha-olefin including two or more carbon atoms on each ...

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Номер записи: 42
03-03-2016 дата публикации

Polyalkyl succinic anhydride derivatives as additives for fouling mitigation in petroleum refinery processes

Номер: US20160060552A1
Автор: Donna J. Crowther, Glen Barry Brons, Hong Cheng, Kevin Mallory, Man Kit Ng, Patrick Brant, Steven Webster Levine
Принадлежит: ExxonMobil Research and Engineering Co

The present invention provides a method for reducing fouling, including particulate-induced fouling, in a hydrocarbon refining process including the steps of providing a crude hydrocarbon for a refining process; adding at least one polyalkyl succinic anhydride derivative additive disclosed herein. The additive can be complexed with a boronating agent, such as boric acid, to yield a boron-containing polyalkyl succinic anhydride derivative.

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Номер записи: 43
21-02-2019 дата публикации

KINETIC HYDRATE INHIBITORS FOR CONTROLLING GAS HYDRATE FORMATION IN WET GAS SYSTEMS

Номер: US20190055484A1
Автор: Bartels Jeremy Wayne, Jones Regan Andrew, Servesko Jeff Michael
Принадлежит:

Polymers are provided for use in inhibiting gas hydrate formation and/or corrosion in hydrocarbon-containing fluids. The polymer comprises repeat units derived from a first monomer comprising N-[3-(dibutylamino)propyl]methacrylamide (DBAPAMA) or an alkyl, acetyl, acryloyl or benzyl quaternary salt thereof, N-[3-(diisobutyl)propyl]methacrylamide or an alkyl, acetyl, acryloyl or benzyl quaternary salt thereof, N-[3-(diisopentyl)propyl]methacrylamide or an alkyl, acetyl, acryloyl or benzyl quaternary salt thereof, or a combination thereof; and repeat units derived from a second monomer comprising acrylamide, N-alkylacrylamide, N-alkyl (alkyl)acrylamide, ((dialkylamino)alkyl)acrylamide or an alkyl or benzyl quaternary salt thereof, ((dialkylamino)alkyl)alkylacrylamide or an alkyl or benzyl quaternary salt thereof, acrylic acid, alkyl acrylate, N,N-(dialkylamino)alkyl acrylate or an alkyl or benzyl quaternary salt thereof, N,N-(dialkylamino)alkyl (alkyl)acrylate or an alkyl or benzyl quaternary salt thereof, hydroxyalkyl acrylate, hydroxyalkyl (alkyl)acrylate, acrylamido alkyl sulfonic acid or a salt thereof, a diallyl dialkyl quaternary ammonium salt, or a combination thereof. The second monomer does not comprise the first monomer. 1. A polymer comprising:repeat units derived from a first monomer comprising N-[3-(dibutylamino)propyl]methacrylamide (DBAPAMA) or an alkyl, acetyl, acryloyl or benzyl quaternary salt thereof, N-[3-(diisobutyl)propyl]methacrylamide or an alkyl, acetyl, acryloyl or benzyl quaternary salt thereof, N-[3-(diisopentyl)propyl]methacrylamide or an alkyl, acetyl, acryloyl or benzyl quaternary salt thereof, or a combination thereof; andrepeat units derived from a second monomer comprising acrylamide, N-alkylacrylamide, N-alkyl (alkyl)acrylamide, ((dialkylamino)alkyl)acrylamide or an alkyl or benzyl quaternary salt thereof, ((dialkylamino)alkyl)alkylacrylamide or an alkyl or benzyl quaternary salt thereof, acrylic acid, alkyl acrylate, N,N-( ...

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Номер записи: 44
04-03-2021 дата публикации

STABILIZATION OF COMPOSITIONS COMPRISING QUATERNARY TRIALKYLALKANOLAMINE HYDROXIDE

Номер: US20210061754A1
Автор: RUDOLPH Tim, Urschey Michael
Принадлежит: KURITA WATER INDUSTRIES LTD.

A composition comprising a) a quaternary trialkylalkanolamine hydroxide and b) at least one diamine as component b), which is selected from the group consisting of 1-amino-4-methylpiperazine, 1,2-diaminopropane and mixtures thereof. 1. A composition comprising a) a quaternary trialkylalkanolamine hydroxide and b) at least one diamine as component b) , which is selected from the group consisting of 1-amino-4-methylpiperazine , 1 ,2-diaminopropane and mixtures thereof.2. The composition according to claim 1 , wherein component b) is 1-amino-4-methylpiperazine.3. The composition according to claim 1 , wherein component b) is 1 claim 1 ,2-diaminopropane.4. The composition according to claim 1 , wherein component b) is a mixture of 1-amino-4-methylpiperazine and 1 claim 1 ,2-diaminopropane.5. The composition according to claim 4 , wherein the weight ratio of 1-amino-4-methylpiperazine to 1 claim 4 ,2-diaminopropane is in the range of 1:9 to 9:1 claim 4 , preferably of 1:9 to 4:6.6. The composition according to claim 1 , wherein the component a) is N claim 1 ,N claim 1 ,N-trimethyl-hydroxyethyl-ammonium hydroxide.7. The composition according to claim 1 , wherein the concentration of component a) is in the range of 5 to 60% by weight claim 1 , preferably in the range of 20 to 60% by weight claim 1 , based on the total weight of the composition.8. The composition according to claim 1 , wherein the concentration of component b) is in the range of 0.1 to 3% by weight claim 1 , preferably in the range of 0.1 to 1% by weight claim 1 , based on the total weight of the composition.9. The composition according to claim 1 , which is an aqueous composition.10. The composition according to claim 1 , further comprising at least one component c) selected from the group consisting of N claim 1 ,N-diethylhydroxylamine claim 1 , diethylentriamine claim 1 , ethylenediamine claim 1 , hydroxylamine or hydroxylamine salts.11. The composition according to claim 10 , comprising 1-amino-4- ...

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Номер записи: 45
02-03-2017 дата публикации

Predicting Solvent Power of Light Oils

Номер: US20170058216A1
Автор: Balashanmugam Soban, Fisher Ronald, Halliday Devin, Rueda-Velasquez Rosa
Принадлежит: BP CORPORATION NORTH AMERICA INC.

A method for recalculating the solvent power of a light oil, SP, is provided. The method comprises: 2. The method of claim 1 , wherein titration intervals of less than 15% by weight are used for titrating the light oil against the reference oil.3. The method of claim 1 , wherein the light oil is titrated against the reference oil in the presence of a titrant and x is 1.4. The method of claim 1 , wherein the method comprises titrating the light oil against a plurality of reference oils claim 1 , predicting a solvent power of the light oil for each of the plurality of reference oils and determining an average predicted solvent power of the light oil.5. The method of claim 4 , wherein the light oil is titrated against at least 5 reference oils.6. The method of claim 1 , wherein the solvent power of the reference oil claim 1 , SP claim 1 , is estimated from the characterisation K factor of the reference oil.7. The method of claim 1 , wherein the critical solvent power of the reference oil claim 1 , CSP claim 1 , is determined by titrating the reference oil against a precipitant.8. The method of claim 1 , wherein the light oil has an asphaltene content of less than 1% by weight.9. The method of claim 1 , wherein the reference oil has an asphaltene content of greater than 3% by weight.10. The method of claim 1 , wherein the light oil and the reference oil are crude oils.11. A method for determining a relationship between the recalculated solvent power and the bulk properties of lights oils claim 1 , said method comprising:{'claim-ref': {'@idref': 'CLM-00001', 'claim 1'}, 'determining the recalculated solvent power for a plurality of light oils using a method in accordance with ; and'}determining a relationship between the recalculated solvent power and the bulk properties of the plurality of light oils.12. The method of claim 11 , wherein the method comprises measuring the bulk properties of the plurality of light oils.13. The method of claim 11 , wherein the plurality of ...

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Номер записи: 46
02-03-2017 дата публикации

Predicting High Temperature Asphaltene Precipitation

Номер: US20170058217A1
Автор: Balashanmugam Soban, Fisher Ronald, Halliday Devin
Принадлежит: BP CORPORATION NORTH AMERICA INC.

A method for determining a relationship between the ratio of solvent power to critical solvent power and the threshold light paraffin content of a hydrocarbon fluid is provided. The method comprises: 1. A method for determining a relationship between the ratio of solvent power to critical solvent power and the threshold light paraffin content of a hydrocarbon fluid , said method comprising:dividing a plurality of hydrocarbon fluids into subgroups, based on the ratio of solvent power to critical solvent power,for each of the subgroups, determining the threshold light paraffin content, said threshold light paraffin content being the light paraffin content of the hydrocarbon fluids at the point at which the fouling tendency of the hydrocarbon fluids exceeds a fouling threshold; anddetermining a relationship between the ratio of solvent power to critical solvent power and the threshold light paraffin content.2. The method of claim 1 , wherein the fluid is divided into at least 3 subgroups.3. The method of claim 1 , wherein each subgroup contains at least 2 hydrocarbon fluids.4. The method of claim 1 , wherein each of the subgroups has a size of up to 0.1 ratio units.5. The method of claim 1 , wherein the method comprises measuring the fouling tendency of the hydrocarbon fluids.6. The method of claim 5 , wherein the fouling tendency of the hydrocarbon fluids is determined by measuring the mass of deposits produced by the hydrocarbon fluids claim 5 , or by looking at the change in heat exchange with the hydrocarbon fluids as a result of deposits.7. The method of claim 5 , wherein the fouling tendency of the hydrocarbon fluids is determined by subjecting the hydrocarbon fluids to conditions which simulate the effect of a refinery on the hydrocarbon fluids.8. The method of claim 5 , wherein the fouling tendency of the hydrocarbon fluids is determined by carrying out hot liquid process simulator tests.9. The method of claim 1 , wherein the light paraffin content of the ...

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Номер записи: 47
04-03-2021 дата публикации

Modified Phenol Polymer and Use Thereof

Номер: US20210061944A1
Автор: Joseph T. DOANE, Kelly S. CHICHAK
Принадлежит: SI Group Inc

A polymer, such as for use in a petroleum composition, is provided. The polymer has at least the following repeating unit (I): wherein, R 1 includes an alkyl, an alkenyl, an alkynyl, an aryl, an amine, or -A-Y—R 10 wherein A is a direct bond or an alkylene; Y is —C(O)O—, —OC(O)—, —C(O)N(R 11 )—, —N(R 11 )C(O)—, —C(O)—, —N(R 11 )—, —O—, or —S—; R 10 includes an alkyl, an alkenyl, an alkynyl, an aryl, or a polyether; and R 11 is H or an alkyl; R 2 is an alkylene; X is —O—, —N—, —O—C(O)—, or —N—C(O)—; R 3 includes an alkyl, an alkenyl, an alkynyl, or an aryl; R 4 includes H, an alkyl, an alkenyl, an alkynyl, or an aryl; and p is 0 when X is —O—, —O—C(O)—, or —N—C(O)— and p is 1 when X is —N—. The present invention also provides a method for forming the aforementioned polymer containing the aforementioned repeating unit (I) as well as a method for using the aforementioned polymer containing the aforementioned repeating unit (I).

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Номер записи: 48
17-03-2022 дата публикации

SYSTEM AND METHOD FOR IDENTIFICATION AND FORECASTING FOULING OF HEAT EXCHANGERS IN A REFINERY

Номер: US20220083716A1
Автор: DEODHAR Anirudh, JADHAV Vishal Sudam, RUNKANA VENKATARAMANA, SRINIVAS Sakhinana Sagar
Принадлежит: TATA CONSULTANCY SERVICES LIMITED

Fouling is formation of deposits on the heat exchanger surfaces that adversely affects operation of heat exchanger. Fouling can be approximated through a set of estimated heat exchanger parameters, which may not be accurate, leading to uncertainty in operation/maintenance decisions and hence the losses. A system and a method for identification and forecasting fouling of a plurality of heat exchangers in a refinery has been provided. The system comprises a digital replica of the heat exchanger network. The digital replica is configured to receive real-time sensor data from a plurality of data sources and provides real-time soft sensing of key parameters. The system is also configured to diagnose the reasons behind a specific condition of fouling. Further, an advisory is provided, that alerts and recommends corrective actions. The system provides estimate for the remaining useful life (RUL) of the heat exchangers and suggests the cleaning schedule. 1. A processor implemented method for identification and forecasting fouling of a plurality of heat exchangers in a refinery , the method comprising:receiving, via one or more hardware processors, a plurality of data related to a heat exchanger network from a plurality of data sources, wherein the heat exchanger network comprises a plurality of heat exchangers in the refinery;preprocessing, via the one or more hardware processors, the received plurality of data using a plurality of pre-built models present in a data transformation unit;soft sensing, via the one or more hardware processors, a plurality of operating parameters, a plurality of fouling parameters and a fouling propensity index for each heat exchanger amongst the plurality of heat exchangers using pre-built models present in an observer unit;detecting in real-time, via the one or more hardware processors, a root cause of fouling by comparing the soft sensed plurality of operating parameters, the plurality of fouling parameters and the fouling propensity index ...

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Номер записи: 49
17-03-2016 дата публикации

Functionalized polymers containing polyamine succinimide for antifouling in hydrocarbon refining processes

Номер: US20160075648A1
Автор: Clarence CHASE, David T. Ferrughelli, Donna J. Crowther, Edward Andrew Lemon, Emmanuel ULYSSE, Geoffrey Marshall KEISER, Glen Barry Brons, Hong Cheng, Man Kit Ng, Mohsen Shahmirzadi YEGANEH, Timothy Andrew Barckholtz
Принадлежит: ExxonMobil Research and Engineering Co

A multipurpose chemical additives (MPC) is disclosed to mitigate fouling in hydrocarbon refinery processes, such as in a heat exchanger. A method for reducing fouling of a hydrocarbon is also disclosed that includes (i) providing a crude hydrocarbon for a refining process; and (ii) adding an additive to the crude hydrocarbon.

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Номер записи: 50
17-03-2016 дата публикации

Functionalized polymers containing polyamine succinimide for antifouling in hydrocarbon refining processes

Номер: US20160075649A1
Автор: Clarence CHASE, David T. Ferrughelli, Donna J. Crowther, Edward Andrew Lemon, Emmanuel ULYSSE, Geoffrey Marshall KEISER, Glen Barry Brons, Hong Cheng, Man Kit Ng, Mohsen Shahmirzadi YEGANEH, Timothy Andrew Barckholtz
Принадлежит: ExxonMobil Research and Engineering Co

A multipurpose chemical additives (MPC) is disclosed to mitigate fouling in hydrocarbon refinery processes, such as in a heat exchanger. A method for reducing fouling of a hydrocarbon is also disclosed that includes (i) providing a crude hydrocarbon for a refining process; and (ii) adding an additive to the crude hydrocarbon.

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Номер записи: 51
17-03-2016 дата публикации

Method and Apparatus For Reducing Phosphorus In Crude Refining

Номер: US20160075956A1
Автор: Adams Phillip Ryan, Johnson James F.
Принадлежит: MARATHON PETROLEUM COMPANY LP

A method and apparatus for the reduction of fouling in a crude unit. Chemicals containing Phosphorous are understood to be utilized in the production or transportation of certain types of crude oils. It is believed that the elevated levels of phosphorus are contributing to the excessive fouling observed in the preheat exchanger circuits and crude heaters. 1. A method of reducing the levels of phosphorous in the process of refining oil comprising the steps of:heating crude oil, to a temperature exceeding 450° F.;transferring the heated crude oil to a flash separator;separating and removing kerosene from the crude oil in the flash separator; andtransferring the separated crude oil to a crude heater.2. The method according to wherein the flash separator is a flash drum.3. The method according to wherein the flash separator is a flash tower.4. The method according to wherein the flash separator is a flash drum and a flash tower.5. The method according to wherein the crude oil is heated to a temperature exceeding 475° F.6. The method according to wherein the crude oil is heated to a temperature exceeding 500° F.7. The method according to wherein the crude oil is heated to a temperature ranging between 450-500° F.8. The method according to wherein the crude oil is heated with multiple heat exchangers.9. A method of refining oil comprising the steps of:heating a crude oil to a temperature exceeding 450° F.;transferring the heated crude oil to a flash drum;separating and removing kerosene from the crude oil in the flash drum;transferring the crude oil to a flash tower;further separating and removing kerosene from the crude oil in the flash tower; andtransferring the separated crude oil to a crude heater.10. A method of refining oil comprising the steps of:heating crude oil to a temperature exceeding 450° F.;transferring the heated crude oil to a flash tower;separating and removing kerosene from the crude oil in the flash tower; andtransferring the separated crude oil to a ...

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Номер записи: 52
07-03-2019 дата публикации

METHODS AND COMPOSITIONS FOR PREVENTION OF FOULING IN CAUSTIC TOWERS

Номер: US20190071610A1
Автор: HONG Mike, SHI Yongtao, TANG Xiaofeng, XU Chun, YAN Dengchao, Zhang Guixi
Принадлежит:

Provided are methods and compositions for inhibiting carbonyl based fouling materials of basic wash systems. Said methods comprise contacting the hydrocarbon stream that is or will be subjected to said wash systems with water soluble or water dispersible copolymers. Said copolymers comprise repeat units of ethylenically unsaturated monomers such as acrylic acid with other repeat units such as alkyl acrylates, allyl ethers, ethoxylated allyl repeat units, etc. In other embodiments, a third repeat unit is present and may comprise a hydrophobic moiety such as a styrene repeat unit. 2. The method of claim 1 , wherein about 1-2 claim 1 ,000 ppm of said antifoulant is brought into contact with said hydrocarbon stream claim 1 , based upon 1 million parts of said stream by weight.3. The method of claim 1 , wherein said polymer is a copolymer of acrylic acid (AA) acid/allyl ether or (AA)/allyl hydroxylated alkyl ether.4. (canceled)5. The method of claim 1 , wherein said polymer is a terpolymer of AA/AHP SE/styrene.6. The method of claim 1 , wherein said polymer is a copolymer of AA/allylpolyethyleneglycol ether or AA/ethoxylated allyl ether.7. The method of claim 6 , wherein said ethoxylated allyl ether is allylpolyethyoxy (10) sulfate.8. The method of claim 1 , wherein said polymer is a terpolymer of AA/AHPSE/ammonium allylpolyethoxy (10) sulfate or a copolymer of AA/lower alkyl (C-C) acrylate.9. The method of claim 8 , wherein said lower alkyl (C-C) acrylate is an hydroxy alkyl acrylate.10. The method of claim 9 , wherein said hydroxy alkyl acrylate is 2 hydroxypropyl acrylate (HPA).11. The method of claim 1 , wherein said polymer is a terpolymer of AA/HPA/AHP SE/styrene.12. (canceled)13. The method of claim 1 , wherein the antifoulant is added to the hydrocarbon stream simultaneously with the base wash or is added to the hydrocarbon stream in a hydrocarbon charge line to a basic wash tower or is added to the hydrocarbon stream in an input line to or recycle line from a ...

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Номер записи: 53
05-03-2020 дата публикации

Passivation and Removal of Crosslinked Polymer Having Unites Derived from Vinyl Aromatics

Номер: US20200071622A1
Автор: Malhotra Monica, Moran Michael, Sangar Neeraj, Wadhwa Kuldeep, Yu Renyuan
Принадлежит:

Methods are provided for passivating and/or solubilizing crosslinked popcorn polymer formed from vinyl aromatic precursors. The passivation and/or solubilization can be performed by exposing the crosslinked popcorn polymer to an aromatics-containing solvent at a suitable temperature and/or by heat treating the crosslinked popcorn polymer in the presence of steam and oxygen followed by exposure to an aromatics-containing solvent. The vinyl aromatic polymer can be exposed to the aromatics-containing solvent for a suitable period of time at a temperature of 200° C. or more. Optionally, the aromatics-containing solvent can be at least partially in the liquid phase during the exposure of the vinyl aromatic polymer. 1. A method for treating crosslinked vinyl aromatic polymer deposits for passivation and solubility enhancement , comprising:exposing crosslinked vinyl aromatic polymer deposited on one or more surfaces within a process vessel to a temperature of 220° C. or more in the presence of a solubility-enhancing environment to form heat-treated polymer deposits; andexposing the heat-treated polymer deposits to a solvent containing aromatics to remove at least a solubilized portion of the heat-treated polymer deposits, the solubilized portion of the heat-treated polymer deposits corresponding to 40 wt. % or more of a weight of the crosslinked vinyl aromatic polymer.2. The method of claim 1 , wherein (i) exposing the crosslinked vinyl aromatic polymer to a temperature of 220° C. or more in the presence of a solubility-enhancing environment comprises exposing the crosslinked vinyl aromatic polymer to the temperature in a gas phase environment comprising 0.1 wt. % to 5.0 wt. % of O claim 1 , and (ii) the solvent comprises ≥90 wt. % of aromatics and ≤0.1 wt. % of non-aromatics3. The method of claim 2 , wherein the temperature is 260° C. or more (or 275° C. or more).4. The method of claim 2 , wherein the gas phase environment comprises 0.5 wt. % to 5.0 wt. % O.5. The method ...

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Номер записи: 54
05-03-2020 дата публикации

Pyrolysis Tar Upgrading

Номер: US20200071627A1
Автор: Clemmons Michael J., Coleman John S., FERRUGHELLI David T., Heeter Glenn A., Kandel Kapil, McMANUS Jesse R., Xu Teng
Принадлежит:

A process id disclosed for upgrading tars, typically those resulting from hydrocarbon refining processes, to products suitable for other uses, such as blending with other hydrocarbons to provide low-sulfur fuel oils or Emission Control Area-acceptable fuels. A low-sulfur hydrocarbon product obtained from the process is also disclosed. 1. A process for preparing a low sulfur liquid hydrocarbon product comprising:i) heat soaking a tar stream to obtain a first process stream comprising reduced reactivity tar;ii) blending the first process stream with a utility fluid to reduce the viscosity of the first process stream and obtain a second process stream comprising reduced reactivity, lower viscosity tar;iii) removing solids from the second process stream to provide a third process stream comprising a reduced reactivity, lower viscosity tar that is substantially free of solids of size larger than 25 μm;iv) pretreating the third process stream to further lower the reactivity of the tar and obtain a fourth process tar stream having a Bromine Number (BN) lower than 12;v) hydrogenating and desulfurizing the fourth process stream and recovering a total liquids product (TLP);vi) distilling the TLP and recovering a mid-cut of the distillation products and a heavy bottoms fraction;vii) desulfurizing the heavy bottoms fraction to obtain a low sulfur product having a sulfur content of about 0.3 wt. % or less.2. The process of claim 1 , further comprising recycling a portion of the mid-cut as at least a portion of the utility fluid used in step ii).3. The process of claim 1 , further comprising blending the low sulfur product with an aromatic gas oil.4. The process of claim 1 , further comprising producing an ECA stream that includes the low sulfur product.5. The process of claim 1 , wherein the reduced reactivity tar has a reactivity <28 BN.6. The process of claim 1 , wherein the heat soaking step is performed at a temperature in the range of from 200° C. to 300° C. claim 1 , and ...

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Номер записи: 55
05-03-2020 дата публикации

TREATMENT OF SULFIDE SCALES

Номер: US20200071641A1
Автор: Cooper Brent, Hull Katherine Leigh
Принадлежит: Saudi Arabian Oil Company

Treating a sulfide scale includes contacting the sulfide scale with an oxidizing composition that includes a first oxidizer and a second oxidizer. 1. A method comprising treating iron sulfide scale associated with a subterranean formation , the treating comprising contacting the iron sulfide scale with an aqueous oxidizing composition comprising ammonium persulfate and a bromate.2. The method of claim 1 , wherein contacting the iron sulfide scale with the aqueous oxidizing solution dissolves at least a majority of the iron sulfide scale contacted by the aqueous oxidizing solution.3. The method of claim 1 , wherein contacting the iron sulfide scale with the aqueous oxidizing composition occurs for less than 96 hours.4. The method of claim 1 , wherein the aqueous oxidizing composition dissolves the iron sulfide scale faster and to a greater extent than the aqueous oxidizing composition without the ammonium persulfate claim 1 , and wherein the aqueous oxidizing composition dissolves the iron sulfide scale faster and to a greater extent than the aqueous oxidizing composition without the bromate.5. The method of claim 1 , wherein the bromate comprises sodium bromate.6. The method of claim 1 , wherein contacting the iron sulfide scale with the aqueous oxidizing composition comprises pumping the aqueous oxidizing composition into the subterranean formation.7. The method of claim 1 , wherein contacting the iron sulfide scale with the aqueous oxidizing composition comprises pumping the aqueous oxidizing composition through equipment in the subterranean formation.8. The method of claim 1 , wherein contacting the iron sulfide scale with the aqueous oxidizing composition comprises removing equipment from the subterranean formation and applying the aqueous oxidizing composition to the equipment as removed.9. The method of claim 1 , wherein contacting the iron sulfide scale with the aqueous oxidizing composition comprises applying the aqueous oxidizing composition to downstream ...

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Номер записи: 56
18-03-2021 дата публикации

Predicting Solvent Power of Light

Номер: US20210079306A1
Автор: Balashanmugam Soban, Fisher Ronald, Halliday Devin, Rueda-Velasquez Rosa
Принадлежит:

A method for recalculating the solvent power of a light oil, SP, is provided. The method comprises: 2. The method of claim 1 , wherein titration intervals of less than 15% by weight are used for titrating the light oil against the reference oil.3. The method of claim 1 , wherein the light oil is titrated against the reference oil in the presence of a titrant and x is 1.4. The method of claim 1 , wherein the method comprises titrating the light oil against a plurality of reference oils claim 1 , predicting a solvent power of the light oil for each of the plurality of reference oils and determining an average predicted solvent power of the light oil.5. The method of claim 4 , wherein the light oil is titrated against at least 5 reference oils.6. The method of claim 1 , wherein the solvent power of the reference oil claim 1 , SP claim 1 , is estimated from the characterisation K factor of the reference oil.7. The method of claim 1 , wherein the critical solvent power of the reference oil claim 1 , CSP claim 1 , is determined by titrating the reference oil against a precipitant.8. The method of claim 1 , wherein the light oil has an asphaltene content of less than 1% by weight.9. The method of claim 1 , wherein the reference oil has an asphaltene content of greater than 3% by weight.10. The method of claim 1 , wherein the light oil and the reference oil are crude oils.11. A method for determining a relationship between the recalculated solvent power and the bulk properties of lights oils claim 1 , said method comprising:{'claim-ref': {'@idref': 'CLM-00001', 'claim 1'}, 'determining the recalculated solvent power for a plurality of light oils using a method in accordance with ; and'}determining a relationship between the recalculated solvent power and the bulk properties of the plurality of light oils.12. The method of claim 11 , wherein the method comprises measuring the bulk properties of the plurality of light oils.13. The method of claim 11 , wherein the plurality of ...

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Номер записи: 57
18-03-2021 дата публикации

APPARATUS TO SIMULATE BIOCIDE PERFORMANCE IN CRUDE PIPELINE CONDITIONS

Номер: US20210079307A1
Автор: Al-Saleh Mazen A., Ali Qurban, Zhu Xiangyang
Принадлежит:

An apparatus to simulate biocide performance in crude oil pipeline conditions is disclosed. The apparatus includes: a reactor to simulate a two-phase crude oil pipeline which includes a crude oil phase above a water phase. The reactor has an agitator to control a flow of the water phase in the reactor in response to a motor that drives an agitation rate of the agitator. A crude oil inlet supplies crude oil to the reactor for the crude oil phase. A water inlet supplies water to the reactor for the water phase. A control circuit is configured by code to control a proportion of the water to the crude oil supplied to the reactor and to control the motor to drive a desired agitation rate of the agitator. A biocide inlet supplies biocide to the reactor. A water sample outlet enables sampling of the water phase of the reactor. 1. An apparatus to simulate biocide performance in crude oil pipeline conditions , the apparatus comprising:a reactor to simulate a two-phase crude oil pipeline and including a crude oil phase above a water phase, the reactor comprising an agitator to control a flow of the water phase in the reactor in response to a motor that drives an agitation rate of the agitator;a crude oil inlet to supply crude oil to the reactor for the crude oil phase;a water inlet to supply water to the reactor for the water phase; control a proportion of the water to the crude oil supplied to the reactor by the crude oil inlet and the water inlet, and', 'control the motor to drive a desired agitation rate of the agitator;, 'a control circuit configured by logic or code toa biocide inlet to supply biocide to the reactor; anda water sample outlet to sample the water phase of the reactor.2. The apparatus of claim 1 , whereinthe reactor further comprises a plurality of reactors each having a dedicated biocide inlet and a dedicated water sample outlet, andthe control circuit is further configured by logic or code to independently control the proportion of the water to the crude ...

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Номер записи: 58
18-03-2021 дата публикации

Refinery Antifoulant Process

Номер: US20210079308A1
Автор: Andrew C. Sulkowski, Colin Morton, Krzysztof J. Maranski, Paul D. Kerby
Принадлежит: Infineum International Ltd

Fouling in a refinery vessel, such as heat transfer equipment, used in a petroleum refinery operation and in which a refineable petroleum feedstock is at an elevated temperature and in fluid communication with the refinery vessel during a petroleum refinery operation, is reduced by providing in the refineable petroleum feedstock an additive comprising (i) a poly(butylenyl)benzene sulphonic acid; or, (ii) a poly(propylenyl)benzene sulphonic acid; or, (iii) a combination of a poly(butylenyl)benzene sulphonic acid and a poly(propylenyl)benzene sulphonic acid.

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Номер записи: 59
14-03-2019 дата публикации

COMPOSITION AND METHOD FOR DISPERSING SCALES AND SOLID DEPOSITS

Номер: US20190078030A1
Автор: Choudary Nettem Venkateswarlu, NAGA Raja Kanuparthy, RAO Peddy Vankata Chalapathi, Sriganesh Gandham, VANKATESWARLU Cheerladinne
Принадлежит:

The present disclosure relates to a composition for removing scales and solid deposits. The composition comprises at least one dispersant salt, at least one hydrocarbon, and at least one ionic liquid. 1. A dispersant composition for removing scales and solid deposits from a location selected from at least one of the inner walls of a reactor , the inner walls of pipelines , the inner walls of heat exchangers , valves and a catalyst bed , said composition comprising:at least one dispersant salt in the range of 2 wt % to 60 wt %;{'sub': 1', '50, 'at least one hydrocarbon in the range of 40 wt % to 85 wt %; said hydrocarbon is selected from the group consisting of Cto Ccarbon atom(s); and'}at least one additive in the range of 0.1 wt % to 45 wt %; said additive is selected from the group of ionic liquids.2. The dispersant composition as claimed in claim 1 , wherein said additive is at least one selected from the group consisting of 1-butyl-3-methylimidazolium tetrafluoroborate claim 1 , tributylmethylammonium methyl sulfate claim 1 , 1-butyl-3-methylimidazolium hexafluorophosphate and trihexyltetradecylphosphonium bis(2 claim 1 ,4 claim 1 ,4trimethylpentyl)phosphinate.3. The dispersant composition as claimed in claim 1 , wherein said scales and solid deposits comprise at least one organic and/or inorganic deposits such as sand claim 1 , grits claim 1 , iron sulfide particles and organic gums.4. A method for preparing the dispersant composition as claimed in claim 1 , wherein said method comprises the following steps: cooling an acid to a first pre-determined temperature to obtain a cooled acid;', 'cooling a base to a second pre-determined temperature to obtain a cooled base;', 'adding said cooled base to said cooled acid at a pre-determined rate while stirring at a pre-determined speed, at a third pre-determined temperature, and for a pre-determined time period to obtain said dispersant salt;, 'a) preparing a dispersant salt byb) adding at least one hydrocarbon to at ...

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Номер записи: 60
22-03-2018 дата публикации

DISPERSING ADDITIVE FOR ASPHALTENES AND ITS USES

Номер: US20180079976A1
Автор: PASSADE-BOUPAT Nicolas, QUINTERO Carlos, RONDON Marianna, TORT Frédéric
Принадлежит: TOTAL MARKETING SERVICES

Use of an alkylphenol-aldehyde resin modified by at least one alkylamine in a composition of crude oils or in a product derived from a composition of crude oils as dispersing additive for asphaltenes. Process for the treatment of a composition of crude oils or a derived product which makes it possible to prevent the precipitation of asphaltenes, in particular in crude oils and the products which result therefrom by refining and/or extraction processes. Bituminous compositions including an alkylphenol-aldehyde resin modified by at least one alkylamine. 123-. (canceled)24. Method for dispersing asphaltenes and/or for preventing and/or delaying and/or stopping and/or reducing the precipitation of asphaltenes comprised in a composition of crude oils or in a product derived from a composition of crude oils comprising adding to said composition or product at least one modified alkylphenol-aldehyde resin , the said modified alkylphenol-aldehyde resin being capable of being obtained by a Mannich reaction of an alkylphenol-aldehyde condensation resin withat least one aldehyde and/or one ketone having from 1 to 8 carbon atoms;and at least one hydrocarbon compound having at least one alkylamine group having between 1 and 30 carbon atoms,the said alkylphenol-aldehyde condensation resin being itself capable of being obtained by condensationof at least one alkylphenol substituted by at least one linear or branched alkyl group having from 1 to 30 carbon atoms,with at least one aldehyde and/or one ketone having from 1 to 8 carbon atoms.25. Method according to claim 24 , for its employment in a composition of crude oils or in a product derived from a composition of crude oils and comprising asphaltenes subjected to one or more of the following conditions:a rise in pressure,a rise in temperature,a mixing with at least one other fluid.26. Method according to claim 24 , wherein the modified alkylphenol-aldehyde resin is capable of being obtained from p-nonylphenol claim 24 , ...

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Номер записи: 61
22-03-2018 дата публикации

FATTY ALCOHOLS AND ESTERS FOR CRUDE OIL TREATMENT

Номер: US20180079977A1
Автор: Solomon Kim R.
Принадлежит:

Compounds are provided that can be used in methods for reducing paraffin or wax deposition in crude oil during processing, storage, or transportation. More specifically, the method comprises contacting the crude oil with a composition in an amount effective to reduce paraffin or was deposition. 2. The method of claim 1 , wherein the paraffin or wax deposition is reduced by suspension of the paraffin or wax in the crude oil.3. The method of claim 2 , wherein Ris hydrogen.4. The method of claim 2 , wherein Ris —C(O)Rand Ris Cto Calkyl.5. The method of claim 4 , wherein Ris acetyl.6. The method of claim 2 , wherein Ris hydrogen.7. The method of claim 2 , wherein Ris methyl or ethyl.8. The method of claim 2 , wherein Ris Cto Calkyl or Cto Calkenyl.9. The method of claim 8 , wherein Ris octyl claim 8 , nonyl claim 8 , decyl claim 8 , undecyl claim 8 , dodecyl claim 8 , tetradecyl claim 8 , hexadecyl claim 8 , octadecyl claim 8 , icosyl claim 8 , docosyl claim 8 , tetracosyl claim 8 , or hexacosyl.10. The method of claim 2 , wherein the compound of Formula I comprises 1-decanol claim 2 , 1-undecanol claim 2 , 1-dodecanol claim 2 , 1-tetradecanol claim 2 , 1-hexadecanol claim 2 , 1-octadecanol claim 2 , 2-undecanol claim 2 , 2-dodecanol claim 2 , 3-dodecanol claim 2 , 2-heptadecanol claim 2 , 3-octadecanol claim 2 , decyl acetate claim 2 , undecyl acetate claim 2 , dodecyl acetate claim 2 , tetradecyl acetate claim 2 , hexadecyl acetate claim 2 , ocetadecyl acetate claim 2 , undecan-2-yl acetate claim 2 , dodecan-3-yl acetate claim 2 , heptadecan-2-yl acetate claim 2 , octadecan-3-yl acetate claim 2 , or a combination thereof.11. The method of claim 10 , wherein the compound of Formula I comprises dodecyl acetate claim 10 , 1-dodecanol claim 10 , or a combination thereof.12. The method of claim 2 , wherein Ris —C(O)R;{'sub': 2', '3', '12', '616', '4, 'Ris hydrogen; Ris Cto Calkyl; and Ris methyl.'}13. The method of claim 10 , wherein the compound of Formula I comprises ...

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Номер записи: 62
23-03-2017 дата публикации

REMOVAL OF KINETIC HYDRATE INHIBITORS

Номер: US20170080356A1
Автор: Al-Adel Shadi I., Mohammad Ahmad Fadzil, Rithauddeen Megat A.
Принадлежит:

A method includes receiving a water stream from a hydrocarbon production facility, the water stream having a first concentration of a kinetic hydrate inhibitor (KHI); flowing the water stream through a heat exchanger to heat the water stream to a target temperature; mixing the heated water stream with a treatment chemical to form a two-phase mixture, the treatment chemical having an affinity for the KHI; flowing the two-phase mixture into a separator; and physically separating the two-phase mixture into a first phase and a second phase, the first phase including water and having a second concentration of the KHI less than the first concentration, and the second phase including the KHI and the treatment chemical, the density of the second phase being less than the density of the first phase. 1. A method comprising:receiving a water stream from a hydrocarbon production facility, the water stream having a first concentration of a kinetic hydrate inhibitor (KHI);flowing the water stream through a heat exchanger to heat the water stream to a target temperature;mixing the heated water stream with a treatment chemical to form a two-phase mixture, the treatment chemical having an affinity for the KHI;flowing the two-phase mixture into a separator; andphysically separating the two-phase mixture into a first phase and a second phase, the first phase including water and having a second concentration of the KHI less than the first concentration, and the second phase including the KHI and the treatment chemical, the density of the second phase being less than the density of the first phase.2. The method of claim 1 , wherein receiving the water stream comprises:receiving a fluid stream from the hydrocarbon production facility; andseparating the fluid stream into a hydrocarbon stream and the water stream.3. The method of claim 2 , further comprising separating the fluid stream into the hydrocarbon stream claim 2 , the water stream claim 2 , and a gas stream.4. The method of claim ...

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Номер записи: 63
23-03-2017 дата публикации

UPGRADED EBULLATED BED REACTOR WITH INCREASED PRODUCTION RATE OF CONVERTED PRODUCTS

Номер: US20170081599A1
Автор: Mountainland David M., Rueter Michael A., Silverman Brett M., Smith Lee
Принадлежит:

An ebullated bed hydroprocessing system is upgraded using a dual catalyst system that includes a heterogeneous catalyst and dispersed metal sulfide particles to increase rate of production of converted products. The rate of production is achieved by increasing reactor severity, including increasing the operating temperature and at least one of throughput or conversion. The dual catalyst system permits increased reactor severity and provides increased production of converted products without a significant increase in equipment fouling and/or sediment production. In some cases, the rate of production of conversion products can be achieved while decreasing equipment fouling and/or sediment production. 1. A method of upgrading an ebullated bed hydroprocessing system that includes one or more ebullated bed reactors to increase rate of production of converted products from heavy oil , comprising:operating an ebullated bed reactor using a heterogeneous catalyst to hydroprocess heavy oil at initial conditions, including an initial reactor severity and an initial rate of production of converted products;thereafter upgrading the ebullated bed reactor to operate using a dual catalyst system comprised of dispersed metal sulfide catalyst particles and heterogeneous catalyst; andoperating the upgraded ebullated bed reactor using the dual catalyst system at higher reactor severity and increased rate of production of converted products than when operating the ebullated bed reactor at the initial conditions.2. The method of claim 1 , wherein the heavy oil comprises at least one of heavy crude oil claim 1 , oil sands bitumen claim 1 , residuum from refinery processes claim 1 , atmospheric tower bottoms having a nominal boiling point of at least 343° C. (650° F.) claim 1 , vacuum tower bottoms having a nominal boiling point of at least 524° C. (975° F.) claim 1 , resid from a hot separator claim 1 , resid pitch claim 1 , resid from solvent extraction claim 1 , or vacuum residue3. The ...

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Номер записи: 64
23-03-2017 дата публикации

UPGRADED EBULLATED BED REACTOR USED WITH OPPORTUNITY FEEDSTOCKS

Номер: US20170081600A1
Автор: Mountainland David M., Rueter Michael A., Silverman Brett M., Smith Lee
Принадлежит:

An ebullated bed hydroprocessing system is upgraded using a dual catalyst system that includes a heterogeneous catalyst and dispersed metal sulfide particles to hydroprocess opportunity feedstocks (i.e., lower quality heavy oils or lower quality feedstock blends) while maintaining or increasing the rate of production of converted products. The dual catalyst system improves the ability of the upgraded ebullated bed hydroprocessing system to accommodate and withstand negative effects of periodic use of opportunity feedstocks (e.g., without significantly increasing equipment fouling and/or sediment production). In some cases, an upgraded ebullated bed reactor using the dual catalyst system can hydroprocess opportunity feedstocks while decreasing equipment fouling and/or sediment production. 1. A method of upgrading an ebullated bed hydroprocessing system that includes one or more ebullated bed reactors to hydroprocess lower quality heavy oil , comprising:initially operating an ebullated bed reactor using a heterogeneous catalyst to hydroprocess an initial heavy oil feedstock at an initial rate of production of converted products;thereafter upgrading the ebullated bed reactor to operate using a dual catalyst system comprised of dispersed metal sulfide catalyst particles and heterogeneous catalyst; andoperating the upgraded ebullated bed reactor using the dual catalyst system to hydroprocess a lower quality heavy oil and/or a lower quality feedstock blend while maintaining a rate of production of converted products at least as high as the initial rate.2. The method of claim 1 , wherein the lower quality heavy oil and/or the lower quality feedstock blend has at least one lower quality characteristic compared to the initial heavy oil feedstock selected from claim 1 , but not limited to:higher boiling point;higher concentration of sulfur;higher concentration of nitrogen;higher concentration of metals;higher molecular weight;lower hydrogen to carbon ratio;higher asphaltene ...

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Номер записи: 65
23-03-2017 дата публикации

Method for determining a settling rate of at least one foulant in oil-based fluids

Номер: US20170082539A1
Автор: Giuseppe Della Sala, Marco Respini
Принадлежит: Baker Hughes Inc

A settling rate of at least one foulant in oil-based fluids may be determining a settling rate of an oil-based fluid by stirring the fluid during a turbidimetric flocculation titration, which includes solvent dosing and obtaining transmittance measurements of the oil-based fluid. The method may further include stopping the solvent dosing at the onset of flocculation of the foulant(s), stopping the stirring when at least two or more transmittance measurements are substantially similar, and measuring the transmittance of the oil-based fluid to determine a settling rate of the foulant(s). The settling rate may be proportional to an increase in transmittance or decrease in absorbance after the stirring has stopped.

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Номер записи: 66
31-03-2022 дата публикации

DRAG REDUCTION OF ASPHALTENIC CRUDE OILS

Номер: US20220099255A1
Автор: Bao Zhiyi, Burden Timothy L., Dreher, Harris William F., Johnston Ray L., JR. Wayne R., Milligan Stuart N., Olechnowicz Michael, Smith Kenneth W.
Принадлежит:

The process begins by obtaining a first batch of monomers selected from a group of acrylates with a molecular weight equal to or less than butyl acrylate and/or methacrylate with a molecular weight equal to or less than butyl methacrylate. A second batch of monomers is then selected from a group of acrylates with a molecular weight greater than butyl acrylate and/or methacrylate with a molecular weight greater than butyl methacrylate. A mixture is then prepared by mixing the first batch of monomers and the second batch of monomers, wherein the second batch of monomers are greater than 50% by weight of the mixture. Finally, the mixture is polymerized to produce a drag reducing polymer. The drag reducing polymer is capable of imparting drag reducing properties in liquid hydrocarbons. 1. A process , comprising:a) obtaining a first batch of monomers selected from the group consisting of acrylates with a molecular weight equal to or less than butyl acrylate, methacrylates with a molecular weight equal to or less than butyl methacrylate and combinations thereof;b) obtaining a second batch of monomers selected from the group consisting of acrylates with a molecular weight greater than butyl acrylate, methacrylates with a molecular weight greater than butyl methacrylate and combinations thereof;c) preparing a mixture comprising the first batch of monomers and the second batch of monomers wherein the second batch is greater than 50% by weight of the mixture; andd) processing the mixture to produce a drag reducing polymer capable of imparting drag reducing properties in liquid hydrocarbons.2. The process of claim 1 , wherein the drag reducing polymer is introduced into a pipeline claim 1 , such that the friction loss associated with the turbulent flow through the pipeline is reduced by suppressing the growth of turbulent eddies.3. The process of claim 1 , wherein the drag reducing polymer is added to the liquid hydrocarbon in the range from about 0.1 to about 500 ppmw.4. The ...

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Номер записи: 67
12-03-2020 дата публикации

A METHOD OF PRETREATING AND CONVERTING HYDROCARBONS

Номер: US20200080009A1
Автор: DERKS Willem
Принадлежит:

The invention provides a method for pretreating a hydrocarbon steam cracker feed, comprising contacting the feed with a solvent to produce a pretreated feed having a reduced content of fouling components that cause fouling in the preheat, convection and radiant sections of the steam cracker and a rich solvent having an increased content of fouling components. The invention further provides a method for steam cracking hydrocarbons comprising: a) feeding a hydrocarbon steam cracker feed to the process; b) pretreating the feed by contacting the feed with a solvent to produce a pretreated feed having a reduced content of fouling components that cause fouling in the steam cracker and a rich solvent having an increased content of fouling components; c) heating the pretreated feed; and d) passing the pretreated feed through a steam cracker under cracking conditions to produce cracked products. 1. A method of pretreating a hydrocarbon steam cracker feed , comprising contacting the feed with a solvent to produce a pretreated feed having a reduced content of fouling components that cause fouling in the preheat , convection and radiant sections of the steam cracker and a rich solvent having an increased content of fouling components.2. The method of wherein the hydrocarbon steam cracker feed comprises hydrowax claim 1 , hydrotreated vacuum gas oil claim 1 , gasoil claim 1 , slackwax or mixtures thereof.3. The method of wherein the hydrocarbon steam cracker feed comprises pyrolysis oil from plastic waste.4. The method of wherein the fouling components comprise polycyclic aromatics claim 1 , resins or a mixture thereof.5. The method of wherein the pretreated feed has a higher hydrogen content than the hydrocarbon steam cracker feed.6. The method of wherein the fouling components cause fouling by condensing in the transfer line exchangers.7. The method of wherein the solvent is selected from the group consisting of furfural claim 1 , sulfolane claim 1 , toluene claim 1 , N-formyl ...

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Номер записи: 68
02-04-2015 дата публикации

Steam generator additives to minimize fouling and corrosion in crude towers

Номер: US20150090640A1
Автор: Trevor James Dale
Принадлежит: General Electric Co

Dual action amines provide corrosion protection from corrosion and fouling for a steam generator system and distillation tower of a petroleum or petrochemical refinery. These amines are chosen to provide protection for the steam condensate section of the boiler while simultaneously minimizing amine salt fouling and corrosion problems in the crude distillation tower and overhead condensing system of crude distillation units. The distribution ratio of the dual action amine should be about 4.0 or less, the amine pKa should be in the range of about 7.0 to about 11.0, and the amine HCl salt volatility index should be about 2.5 or less.

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Номер записи: 69
19-03-2020 дата публикации

METHOD OF TREATING A HYDROCARBON STREAM

Номер: US20200087582A1
Автор: Al-Dughaither Abdullah Saad, Al-Hamdan Abdulmajeed Mohammed, Alshahrani Dafer Mubarak, Azam Shahid
Принадлежит:

A method of treating a hydrocarbon stream includes: withdrawing an effluent stream comprising hydrocarbons and polymer from a reactor; contacting the effluent stream with a coolant stream; passing the effluent stream through a heat exchanger; wherein after passing the effluent stream through the heat exchanger, the heat exchanger is substantially free of polymer deposits. 1. A method of treating a hydrocarbon stream , comprising:withdrawing an effluent stream comprising hydrocarbons and polymer from a reactor;contacting the effluent stream with a coolant stream;passing the effluent stream through a heat exchanger;wherein after passing the effluent stream through the heat exchanger, the heat exchanger is substantially free of polymer deposits.2. The method of claim 1 , wherein the source of the effluent stream is a product of an ethylene oligomerization process.3. The method of claim 1 , wherein a temperature of the effluent stream is greater than or equal to 45° C. prior to contacting the coolant stream.4. The method claim 1 , wherein the effluent stream comprises ethane claim 1 , methane claim 1 , ethylene claim 1 , butene claim 1 , hexene claim 1 , toluene claim 1 , octene claim 1 , decene claim 1 , catalyst particles claim 1 , or a combination comprising at least one of the foregoing.5. The method of claim 1 , wherein the effluent stream comprises greater than or equal to 1 parts per million polymer.6. The method of claim 1 , wherein the effluent stream comprises 0% to 5% hexene.7. The method of claim 1 , wherein the effluent stream comprises 0 to 50 parts per million active catalyst particles.8. The method of claim 1 , wherein the source of the coolant stream is a product of an ethylene oligomerization process and/or a product of a battery limit process.9. The method of claim 1 , wherein the source of the effluent stream and the coolant stream is a product of the same process.10. The method of claim 1 , wherein the coolant stream comprises a liquid.11. The ...

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Номер записи: 70
19-03-2020 дата публикации

Radiofrequency Pump Inlet Electric Heater

Номер: US20200087583A1
Автор: Pappas C. Dino, Snow Richard H.
Принадлежит:

An apparatus, method and system make possible facile recovery of heavy hydro-carbonaceous materials, such as the bitumen from oil sands, asphalt, tars, pitch and other highly viscous hydrocarbons (HCM) from natural deposits of such material and other storage facilities such as tanks and reservoirs where these materials accumulate. The apparatus and system deliver different inputs of radio frequency energy (RF) to a central collector and one or more outer electrodes. Heat generated by the RF input sufficiently softens the HCM so that a suction pump can withdraw if from the collector and deliver it to a desired location typically for transport and/or processing. The addition of an integral mixer or direct injection of solvents into the apparatus can further improve HCM recovery. 1. A heater arrangement for supplying highly viscous hydro-carbonaceous material (HCM) from a reservoir of HCM to a pump inlet and for transporting said HCM from one location to another , said heater arrangement having an inlet for withdrawing or receiving HCM from the reservoir , said inlet heater comprising:(a) a collector defining an HCM inlet for receiving heated HCM, said collector comprising, at least in part, an electrically conductive material and defining a collector electrical contact for receiving electrical input from a radiofrequency (RF) generator;(b) an HCM outlet defined by the collector for delivering heated HCM to a pump; and(c) at least one electrode having an electrical contact for receiving electrical input from the RF generator that is retained in a spaced relationship with respect the collector to define a space between the electrode and the collector wherein the space is adapted to receive HCM and heat HCM therein when the RF generator delivers electrical input to the collector and the electrode.2. The inlet heater of further comprising a suction line that at one end defines a suction inlet in fluid communication with the HCM outlet and at an opposite end defines a ...

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Номер записи: 71
19-03-2020 дата публикации

THERMAL CRACKING OF CRUDE OIL USING A LIQUID CATALYST TO PREVENT COKE FORMATION AND PROMOTE ALKYLATION

Номер: US20200087586A1
Автор: Echenagucia Cioppa Jorge
Принадлежит:

A system and method for thermal cracking of crude oil is provided. The system includes a plurality of communicatively coupled components configured to support thermal cracking of crude oil and performs a method including a continuous, industrial-sized thermal cracking process used to convert heavy crude oil or extra-heavy crude oil into lighter crude oil, using a liquid catalyst to prevent coke formation and promote alkylation reactions. 1. A method for thermal cracking of crude oil , the method comprising:heating a base crude oil to a first designated heating temperature;based on the base oil reaching the first designated heating temperature, generating an oil-based essence substance;transporting the oil-based essence substance to a separator drum configured to generate a modified oil-based essence substance;filtering, via the separator drum, the oil-based essence substance in order to generate the modified oil-based essence substance;transporting the modified oil-based essence substance to a reactor configured to support application of a liquid catalyst to the modified oil-based essence substance;applying the liquid catalyst to the modified oil-based essence substance in the reactor;heating the reactor to a second designated heating temperature;based on the reactor reaching the second designated heating temperature, generating an optimum oil substance; andcooling the optimum oil substance and storing it in one or more reservoirs.2. The method of claim 1 , wherein the step of cooling the optimum oil substance further comprises:adding a plurality of virgin crude oil to the reactor; andcooling the optimum oil substance via the plurality of virgin crude oil.3. The method of claim 1 , further comprising:storing the optimum oil substance in the reactor for at least four minutes before the step of cooling the optimum oil substance.4. The method of claim 1 , wherein the first designated heating temperature is about 110° C. and the second designated heating temperature is ...

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Номер записи: 72
01-04-2021 дата публикации

DEVICE COMPRISING LATERAL INJECTIONS OF LIQUID FOR LIMITING THE PHENOMENA OF SOLID DEPOSITS IN ITEMS OF EQUIPMENT WITH A CONICAL BOTTOM

Номер: US20210095214A1
Автор: AMBLARD Benjamin, LE COZ Jean-Francois, MARQUES Joao
Принадлежит: IFP ENERGIES NOUVELLES

A device for the descending flow of a hydrocarbon-containing liquid containing solid particles at the bottom of an item of equipment () and a process for the conversion of hydrocarbon-containing feedstocks implementing said device. 249456. The atmospheric or vacuum distillation column or separation drum column according to claim 1 , wherein the device comprises a pipe () for recycling a part of the liquid leaving said outlet pipe () claim 1 , said recycling pipe () supplying recycled liquid to at least one of said at least one injectors () or ().31056. The atmospheric or vacuum distillation column or separation drum column according to claim 1 , wherein the device comprises a makeup pipe () for supplying makeup liquid to at least one of said at least one injectors () or ().45678. The atmospheric or vacuum distillation column or separation drum column according to claim 1 , wherein claim 1 , in the device claim 1 , said at least one injectors () and () are distributed by horizontal layers () in the truncated-cone-shaped part and by horizontal layers () in the cylindrical part claim 1 , respectively.51212. The atmospheric or vacuum distillation column or separation drum column according to claim 1 , wherein claim 1 , in the device claim 1 , the diameter D of the cylindrical part and the diameter D of the outlet pipe at the bottom of the truncated-cone-shaped part has a ratio (D/D) of 1.1 to 1000.6. The atmospheric or vacuum distillation column or separation drum column according to claim 1 , wherein claim 1 , in the device claim 1 , the angle α is 10° to 70°.711. The atmospheric or vacuum distillation column or separation drum column according to claim 1 , wherein claim 1 , in the device claim 1 , the angles β and θ are 10° to 150°.822. The atmospheric or vacuum distillation column or separation drum column according to claim 1 , wherein claim 1 , in the device claim 1 , the angles β and θ are 90° to 180°.922. The atmospheric or vacuum distillation column or ...

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Номер записи: 73
01-04-2021 дата публикации

Methods And Compositions For Prevention Of Fouling In Caustic Towers

Номер: US20210095215A1
Автор: HONG Mike, SHI Yongtao, TANG Xiaofeng, XU Chun, YAN Dengchao, Zhang Guixi
Принадлежит:

Methods and compositions for inhibiting carbonyl-based fouling of basic wash systems. The methods comprise contacting the hydrocarbon stream that is or will be subjected to such washing with water soluble or water dispersible copolymers comprising repeat units of 1) ethylenically unsaturated monomers such as acrylic acid with one or more 2) other repeat units such as alkyl acrylates, allyl ethers, ethoxylated allyl repeat units, etc. In other embodiments, a third repeat unit 3) is present and may comprise a hydrophobic moiety such as a styrene repeat unit. The compositions may be terpolymers comprising repeat units 1), 2), and 3). 2. The method of claim 1 , wherein about 1-2 claim 1 ,000 ppm of said antifoulant is brought into contact with said hydrocarbon stream claim 1 , based upon 1 million parts of said stream by weight.3. The method of claim 1 , wherein said polymer is a copolymer of (i) acrylic acid/allyl ether claim 1 , (ii) acrylic acid/allyl hydroxylated alkyl ether claim 1 , (iii) acrylic acid/allylpolyethyleneglycol ether claim 1 , or (iv) acrylic acid/ethoxylated allyl ether.4. The method of claim 1 , wherein said polymer is a terpolymer of acrylic acid/allyl hydroxypropyl sulfonate ether/styrene.5. The method of claim 3 , wherein said ethoxylated allyl ether is allylpolyethyoxy (10) sulfate.6. The method of claim 1 , wherein said polymer is a terpolymer of acrylic acid/allyl hydroxypropyl sulfonate ether/ammonium allylpolyethoxy (10) sulfate or a copolymer of acrylic acid/lower alkyl (C-C) acrylate.7. The method of claim 6 , wherein said lower alkyl (C-C) acrylate is an hydroxy alkyl acrylate.8. The method of claim 7 , wherein said hydroxy alkyl acrylate is 2 hydroxypropyl acrylate.9. The method of claim 1 , wherein said polymer is a terpolymer of acrylic acid/hydroxypropyl acrylate/allyl hydroxypropyl sulfonate ether/styrene.10. The method of claim 1 , wherein the antifoulant is added to the hydrocarbon stream simultaneously with the base wash or is ...

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Номер записи: 74
06-04-2017 дата публикации

DECREASING FOULANT DEPOSITION ON AT LEAST ONE SURFACE BY CONTACTING THE SURFACE(S) WITH AT LEAST ONE PROTEIN

Номер: US20170096595A1
Автор: Armstrong Charles David, Dhulipala Prasad D.
Принадлежит: BAKER HUGHES INCORPORATED

Corrosion and/or calcium scale deposition on a surface in contact with corrosion forming components and/or scale forming components within a subterranean formation may be decreased, prevented, and/or inhibited by contacting the surface with at least one protein. The protein(s) may be or include, but is not limited to, at least one aspein protein, at least one aspolin protein, at least one dentine protein, at least one DRICH-1 protein, at least one nacrein protein, at least one SMDT-1 protein, derivatives thereof, fragments thereof, mimetics thereof, and combinations thereof. The surface may be or include, but is not limited to a metal surface, a plastic surface, a ceramic surface, a painted surface, a coated surface, and combinations thereof. 1. An additive composition for a base fluid selected from the group consisting of a drilling fluid , a completion fluid , a production fluid , a servicing fluid , an injection fluid , a refinery fluid , and combinations thereof; wherein the additive composition comprises at least one protein selected from the group consisting of at least one aspein protein , at least one aspolin protein , at least one dentine protein , at least one DRICH-1 protein , at least one nacrein protein , at least one SMDT-1 protein , derivatives thereof , fragments thereof , mimetics thereof , and combinations thereof.2. The additive composition of claim 1 , wherein the at least one aspein protein comprises an amino acid sequence that is at least 75% homologous to the amino acid sequence of SEQ ID NO:1; wherein the at least one aspolin protein comprises an amino acid sequence that is at least 75% homologous to the amino acid SEQ ID:2 claim 1 , the amino acid SEQ ID:3 claim 1 , and mimetics thereof; and combinations thereof.3. The additive composition of claim 1 , wherein an amount of the at least one protein within the additive composition ranges from about 0.01 wt % to about 10 wt % as compared to the total base fluid.4. The additive composition of ...

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Номер записи: 75
06-04-2017 дата публикации

ASPHALTENE STABILIZATION IN PETROLEUM FEEDSTOCKS BY BLENDING WITH BIOLOGICAL SOURCE OIL AND/OR CHEMICAL ADDITIVE

Номер: US20170096606A1
Автор: Kremer Lawrence N., PINAPPU SAI REDDY, SANDU CORINA L.
Принадлежит: BAKER HUGHES INCORPORATED

Biological source oils, including, but not limited to, algae oil, stabilize the presence of asphaltenes in petroleum feedstocks, such as crude oil, to help avoid or prevent fouling and/or corrosion in the production, transferring and processing of the petroleum feedstocks. Chemical additives such as phenol-based resins, and reaction products or combinations of long chain alpha-olefins and/or small chain aldehydes and/or long chain alkyl phenate sulfides and/or metal oxide-based colloidal hydrocarbon-based nanodispersions, may also stabilize the presence of asphaltenes in petroleum feedstocks. By “stabilizing” is meant keeping the asphaltenes in solution in the petroleum feedstocks. 2. The petroleum feedstock of where the petroleum feedstock is selected from the group consisting of crude oils claim 1 , heavy oils claim 1 , coker feedstocks claim 1 , visbreaker feedstocks claim 1 , vacuum tower bottoms claim 1 , fuel oils claim 1 , diesel oils claim 1 , bunker fuel oils claim 1 , and mixtures thereof.3. The petroleum feedstock of where the effective amount of biological source oil ranges from about 0.01 wt % to about 99 wt % claim 1 , and the effective amount of the chemical additive ranges from about 0.05 wt % to about 99 wt % claim 1 , both based on the amount of petroleum feedstock.4. The petroleum feedstock of where the biological source oil is algae oil.6. The petroleum feedstock of where the petroleum feedstock is selected from the group consisting of crude oils claim 5 , heavy oils claim 5 , coker feedstocks claim 5 , visbreaker feedstocks claim 5 , vacuum tower bottoms claim 5 , fuel oils claim 5 , diesel oils claim 5 , bunker fuel oils claim 5 , and mixtures thereof.7. The petroleum feedstock of where the effective amount of biological source oil ranges from about 0.01 wt % to about 99 wt % claim 5 , and the effective amount of the chemical additive ranges from about 0.05 wt % to about 99 wt % claim 5 , both based on the amount of petroleum feedstock.8. A ...

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Номер записи: 76
26-03-2020 дата публикации

ESTIMATION OF CYCLONE LIFE BASED ON REMAINING ABRASION RESISTANT LINING THICKNESS

Номер: US20200094211A1
Автор: Panchal Dharmesh Chunilal
Принадлежит:

A Fluid Catalytic Cracking process converts heavy crude oil fractions into lighter hydrocarbon products at high temperature and moderate pressure in the presence of a catalyst. During this process, catalyst particles stay entrained in the descending gas stream. An inlet scroll on the cyclone may be used to keep the inlet gas stream and the entrained particles away from the entrance to the gas outlet tube. Refractory material may applied to the interior of the wall of the cyclone to form an abrasion resistant lining to insulate the walls of the cyclone from the gas flow contents. The inlet feed velocity may be used as a predictive factor to determine a wear rate of the cyclones. Thus, lining erosion can be predicted so that the lining can be repaired or replaced during a planned turnaround. 1. A system comprising:a reactor configured to perform a fluid catalytic cracking process, the reactor including a cyclone with an abrasion resistant lining on an interior wall of the cyclone;a gas flow rate sensor configured to measure a feed velocity of a feed to the cyclone; a processor of the data analysis platform;', receive feed velocity data from the gas flow rate sensor, the feed velocity data indicating the feed velocity of the feed to the cyclone;', 'determine an erosion rate of the abrasion resistant lining on the interior wall of the cyclone based on the feed velocity of the feed to the cyclone;', 'based on the erosion rate, determine a recommended adjustment to an operating parameter of the reactor;', 'send the recommended adjustment to the operating parameter of the reactor; and, 'memory of the data analysis platform, the memory storing executable instructions that, when executed, cause the data analysis platform to], 'a data analysis platform comprising a processor of the control platform; and', receive the recommended adjustment to the operating parameter of the reactor; and', 'adjust the operating parameter of the reactor., 'memory of the control platform, the ...

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Номер записи: 77
26-03-2020 дата публикации

CLEANING AGENT FOR REMOVAL OF FOULING DEPOSITS FROM METAL SURFACES

Номер: US20200095522A1
Автор: Fulmer David N., Hartranft Sara, Legaspi Felipe Mary Jane, Mangadlao Joey Dacula, Pifer Montgomery, Ponnapati Ramakrishna, Taglione Anthony
Принадлежит: Baker Hughes, a GE company, LLC

A cleaning agent comprising a polyacrylate terpolymer and a maleic olefin compound may be added to an aqueous system having a metal surface, such as a metal surface of a heat exchanger, in a concentration sufficient to remove fouling deposits from the metal surface in neutral or alkaline conditions. The removal of fouling deposits with the application of the cleaning agent may occur while the system is shut down or in service. 1. A method of removing fouling deposits from a metal surface in an aqueous system comprising:introducing a cleaning agent comprising a polyacrylate terpolymer and a maleic olefin compound to the aqueous system, the amount of the cleaning agent being effective to remove fouling deposits from a metal surface located in the aqueous system.2. The method of claim 1 , wherein the polyacrylate terpolymer is selected from the group consisting of alkyl functionalized poly(AA-AMPS claim 1 , styrene sulfonate functionalized poly(AA-AMPS) claim 1 , and combinations thereof.3. The method of claim 1 , wherein the maleic olefin compound is a water soluble maleic olefin polymer having a C-Cgroup connected to the maleic olefin backbone through ester claim 1 , amide claim 1 , or imide functionalities.4. The method of claim 1 , wherein the effective amount of the cleaning agent ranges from about 0.1 ppm to about 10000 ppm based on a total amount of fluid in the aqueous system.5. The method of claim 1 , wherein the metal surface is a metal surface of a heat exchanger.6. The method of claim 1 , wherein the aqueous system is selected from the group consisting of a cooling tower claim 1 , a cooling water system claim 1 , an evaporation system claim 1 , a boiler system claim 1 , an air-conditioning system claim 1 , a wastewater treatment system claim 1 , a deionized water system claim 1 , a gas or fluid scrubbing system claim 1 , a gas or fluid absorption system claim 1 , and combinations thereof.7. The method of claim 1 , wherein the aqueous system further ...

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Номер записи: 78
23-04-2015 дата публикации

Process To Produce Oil Or Gas From A Subterranean Formation Using A Chelating Agent

Номер: US20150107832A1
Автор: Cornelia Adriana DeWolf, Edwin Rudolf Antony BANG, Estevao DE OLIVEIRA BARRA, Hisham Nasr-El-Din, Theodor Johannes Stanitzek
Принадлежит: Akzo Nobel Chemicals International BV

The present invention relates to a two-step process to produce oil or gas from a subterranean formation wherein in a first step the subterranean formation is treated with an aqueous composition containing a chelating agent selected from the group of glutamic acid N,N-di-acetic acid or a salt thereof (GLDA), aspartic acid N,N-diacetic acid or a salt thereof (ASDA), methylglycine N,N-diacetic acid or a salt thereof (MGDA), and N-hydroxyethyl ethylenediamine N,N′,N′-triacetic acid or a salt thereof (HEDTA) and wherein, in a next step, in the outlet streams from the subterranean formation the aqueous phase is separated from the non-aqueous phase.

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Номер записи: 79
13-04-2017 дата публикации

ETHYLENE FURNACE PROCESS AND SYSTEM

Номер: US20170101586A1
Автор: BELFADHEL Hatem, Iliyas Abduljelil, SAUDAGAR Munawar
Принадлежит: Sabic Global Technologies B.V.

Methods and systems for managing a decomposition process are disclosed. An example method can comprise estimating a coking rate for a process based on a coking model. The coking model can comprise a pyrolytic coking term and a catalytic coking term. An example method can comprise, performing at least a portion of the process, receiving a parameter for the process, and adjusting an operation of the process based on the parameter. 1. A method , comprising:estimating a coking rate for a process based on a coking model, wherein the coking model comprises a pyrolytic coking term and a catalytic coking term;performing at least a portion of the process;receiving a parameter for the process; andadjusting an operation of the process based on the parameter.2. The method of claim 1 , further comprising performing at least a portion of the process based on the adjusted operation of the process.3. The method of claim 1 , wherein the operation is an anti-coking operation.4. The method of claim 1 , wherein receiving the parameter for the process comprises monitoring in real-time the parameter for the process.5. The method of claim 4 , wherein adjusting the operation comprises adjusting the process in real-time in response to the monitoring.6. The method of claim 1 , wherein adjusting the operation comprises at least one step selected from the group consisting of a) modifying a time to at least one of end the process and interrupt the process claim 1 , and b) scheduling a time to clean a tube implementing the process.7. (canceled)8. (canceled)9. The method of claim 1 , wherein the catalytic term is based on at least one member selected from the group consisting of a) a surface concentration of catalytically active sites and b) a concentration of ethylene.1013.-. (canceled)14. A method claim 1 , comprising:determining a first coking rate for a process based on a coking model, wherein the coking model comprises a pyrolytic coking term and a catalytic coking term;determining a second ...

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Номер записи: 80
08-04-2021 дата публикации

IN-SITU HIC GROWTH MONITORING PROBE

Номер: US20210102888A1
Автор: Sherik Abdelmounam, Traidia Abderrazak
Принадлежит:

The present application concerns in-situ intrusive probe systems and methods. The probe systems described herein can be installed flush to a hydrocarbon containing structure, such as a pipeline, vessel, or other piping system carrying crude, gas or sour products. The probe systems include hydrogen induced cracking (HIC)-resistant microstructure such that as atomic hydrogen permeates the probe surface, the probe captures recombined hydrogen gas. The pressure of the resultant hydrogen gas buildup is measured and predictions as to the HIC activity of that area can be made. 138.-. (canceled)39. An intrusive probe system for flush insertion into a metal asset comprising:a probe body having an access end portion with an exposed surface configured to be exposed to a corrodent located within the metal asset, the access end portion having a recessed portion formed opposite the exposed surface;an insert having an access end and a base end, the access end being disposed adjacent recessed portion of the probe body so as to define a collection cavity that is fluid-tight and configured to collect the atomic hydrogen that permeates through the exposed surface of the probe body, whereby a gas is generated in the collection cavity by the atomic hydrogen, wherein the insert includes a through hole that passes therethrough and is open at both the access end and the base end such that the through hole is in fluid communication with the collection cavity; anda pressure measuring device in fluid communication with the through hole of the probe body for measuring a pressure of the gas generated by the diffused atomic hydrogen within the collection cavity.40. The probe system of claim 39 , wherein the gas generated by the diffused atomic hydrogen in the collection cavity is molecular hydrogen gas.41. The probe system of claim 39 , wherein the recessed portion is formed along a face of the access end portion opposite the exposed surface.42. The probe system of claim 39 , wherein the ...

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Номер записи: 81
04-04-2019 дата публикации

PARAFFIN INHIBITION BY SOLUBILIZED CALIXARENES

Номер: US20190100685A1
Автор: Cable Robert
Принадлежит:

This invention relates to compositions and a process for stabilizing or improving the solubility of a phenolic resin containing a mixture of linear phenolic resins and calixarenes in a hydrocarbon solvent. This invention also relates to a paraffin-containing fluid composition comprising this stabilized (solubilized) calixarene resin. The invention also relates to methods for dispersing paraffin crystals, inhibiting paraffin crystal deposition, or treating a well or vessel to reduce the deposition of paraffin crystals, with a resin composition containing this stabilized (solubilized) calixarene resin. 2. The method of claim 1 , wherein each m is 1.5. The method of claim 1 , wherein each Ris independently a Cto Calkyl or Cto Calkyl.6. The method of claim 1 , wherein the total number of units in the modified calixarene compounds is from 4-8.7. The method of claim 1 , wherein q is 1 in one or more units in the modified calixarene compounds.8. The method of claim 1 , wherein the paraffin-containing fluid is a hydrocarbon fluid selected from the group consisting of a crude oil claim 1 , home heating oil claim 1 , lubricating oil claim 1 , and natural gas.10. The method of claim 9 , wherein each m is 1.13. The method of claim 9 , wherein each Ris independently a Cto Calkyl or Cto Calkyl.14. The method of claim 9 , wherein the total number of units in the modified calixarene compounds is from 4-8.15. The method of claim 9 , wherein q is 1 in one or more units in the modified calixarene compounds.16. The method of claim 9 , wherein the resin composition further comprises a hydrocarbon fluid that the resin is at least partially soluble in claim 9 , selected from the group consisting of a crude oil claim 9 , home heating oil claim 9 , lubricating oil claim 9 , and natural gas.17. The method of claim 16 , wherein the hydrocarbon fluid comprises one or more hydrocarbon solvents selected from the group consisting of kerosene claim 16 , diesel claim 16 , heptane claim 16 , benzene ...

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Номер записи: 82
04-04-2019 дата публикации

Paraffin inhibition by calixarenes

Номер: US20190100686A1
Автор: Robert Cable
Принадлежит: SI Group Inc

This invention relates to a paraffin-containing fluid composition comprising a phenolic resin containing one or more calixarene compounds (i.e., a calixarene resin). The invention also relates to methods for dispersing paraffin crystals, inhibiting paraffin crystal deposition, or treating a well or vessel to reduce the deposition of paraffin crystals, with a calixarene resin.

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Номер записи: 83
21-04-2016 дата публикации

CHEMICAL INHIBITORS WITH SUB-MICRON MATERIALS AS ADDITIVES FOR ENHANCED FLOW ASSURANCE

Номер: US20160108327A1
Автор: KHANDEKAR Chandrashekhar Yeshwant, Pulikkathara Merlyn Xavier
Принадлежит: M-I L.L.C.

Methods may include admixing an additive composition with a hydrocarbon fluid, wherein the additive composition contains at least one inhibitor and at least one sub-micron particle. Additional methods may include providing an additive composition containing at least one inhibitor and at least one sub-micron particle; adding the additive composition to a fluid capable of precipitating at least one of at least of asphaltenes, wax, scale, and gas hydrates; and transporting the fluid containing the additive composition. 1. A method comprising:admixing an additive composition with a hydrocarbon fluid, wherein the additive composition comprises at least one inhibitor and at least one sub-micron particle.2. The method of claim 1 , wherein the at least one sub-micron particle is present at a percent by weight (wt %) of the total fluid weight that ranges from 0.001 wt % to 20 wt %3. The method of claim 1 , further comprising the reducing the deposition or precipitation of at least one of asphaltenes claim 1 , wax claim 1 , scale claim 1 , and hydrates from the hydrocarbon fluid.4. The method of claim 1 , wherein the inhibitor is at least one of a hydrate inhibitor claim 1 , a scale inhibitor claim 1 , or a wax inhibitor.5. The method of claim 1 , wherein the at least one sub-micron particle is is one or more selected from a group consisting of carbon nanotubes claim 1 , carbon fibers claim 1 , fullerenes claim 1 , and graphene particles.6. The method of claim 1 , wherein the at least one sub-micron particle is one or more selected from a group consisting of microcrystalline cellulose claim 1 , nanocrystalline cellulose claim 1 , colloidal silicas claim 1 , hydroxyapatite claim 1 , calcium tertiary phosphate claim 1 , calcium oxide claim 1 , zinc oxide claim 1 , silicon oxide claim 1 , aluminum oxide claim 1 , magnesium oxide claim 1 , and calcium fluoride.7. The method of claim 1 , wherein the at least one sub-micron particle is functionalized.8. The method of claim 7 , ...

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Номер записи: 84
19-04-2018 дата публикации

Design Development and Implementation of Analyzer Based Control System and Algorithm

Номер: US20180105757A1
Автор: Ferguson Sam, Hilton Nigel P., Scattergood Glenn L., Wang Jin
Принадлежит: NALCO COMPANY

A method of correcting measurements of a chemical sensor used in an industrial facility. The method involves correcting for errors known to occur in the steady state and the dynamic state for specifically recognized situations. This method allows for correcting errors that occur due to deadtime, false zero measurements, and non-linear disturbances. The method combines automated measurement techniques and human know how to progressively learn and refine the accuracy of the corrections. 111-. (canceled)12. A method of controlling corrosion rate of a crude oil refinery process comprising:measuring iron or copper concentration of the crude oil refinery process to establish an initial corrosion rate of the crude oil refinery process;measuring pH of the crude oil refinery process;measuring chloride concentration of the crude oil refinery process;measuring at least one of nitrogen, total nitrogen, or ammonia concentration of the crude oil refinery process;altering the initial corrosion rate of the crude oil refinery process according to the measured pH, the measured chloride concentration, and the measured at least one of nitrogen, total nitrogen, or ammonia concentration, and correcting for dynamic state error, thereby determining an altered corrosion rate;comparing the altered corrosion rate to a pre-determined range of acceptable values; andif the altered corrosion rate is outside of the pre-determined range of acceptable values, performing a remedial measure to change the altered corrosion rate to a value within the range of acceptable values.13. The method of claim 12 , wherein the remedial measure comprises adding to the crude oil refinery process a chemical selected from a neutralizer claim 12 , a caustic agent claim 12 , a filming inhibitor claim 12 , or a combination thereof.14. The method of claim 12 , wherein the remedial measure comprises adding a neutralizer to the crude oil refinery process.15. The method of claim 14 , wherein the neutralizer is selected from ...

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Номер записи: 85
20-04-2017 дата публикации

Nanocrystalline cellulose and polymer-grafted nanocrystalline cellulose as rheology modifying agents for magnesium oxide and lime slurries

Номер: US20170107434A1
Автор: Heinrich E. Bode, Rangarani KARNATI, Shayan MOGHADAM
Принадлежит: ECOLAB USA INC

Rheology modifying agents and methods of modifying the rheology of a slurry are disclosed. Methods for the prevention of fouling and methods for monitoring the rheology of a slurry are also provided. The slurry can be a lime slurry or a magnesium oxide slurry, for example. The rheology modifying agent can be polymer-grafted nanocrystalline cellulose. The rheology modifying agent can optionally include other components, such as a chelating agent.

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Номер записи: 86
02-04-2020 дата публикации

NON-SOLVENT CRUDE OIL HEAVY OIL STREAM DE-ASPHALTING PROCESS

Номер: US20200102507A1
Автор: Shaikh Sohel K., SUN Miao, Zhang Zhonglin
Принадлежит:

A process for removing asphaltenes from an oil feed, the process comprising the steps of introducing the oil feed to a de-asphalting column, where the oil feed comprises a carbonaceous material and asphaltenes, where the de-asphalting column comprises a heteropolyacid, operating the de-asphalting column at a reaction temperature and a reaction pressure for a residence time such that the heteropolyacid is operable to catalyze an acid catalyzed polymerization reaction of the asphaltenes to produce polymerized asphaltenes, the polymerized asphaltenes precipitate from the carbonaceous material in the oil feed, and withdrawing a de-asphalted oil from the de-asphalting column, where the de-asphalted oil is in the absence of the heteropolyacids, where the de-asphalted oil has a lower concentration of sulfur, a lower concentration of nitrogen, and a lower concentration of metals as compared to the oil feed, where the process for removing asphaltenes is in the absence of added hydrogen gas. 1. A process for removing asphaltenes from an oil feed , the process comprising the steps of:introducing the oil feed to a de-asphalting column, where the oil feed comprises a carbonaceous material and asphaltenes, where the de-asphalting column comprises a heteropolyacid;operating the de-asphalting column at a reaction temperature and a reaction pressure for a residence time such that the heteropolyacid is operable to catalyze an acid catalyzed polymerization reaction of the asphaltenes to produce polymerized asphaltenes, where the polymerized asphaltenes precipitate from the carbonaceous material in the oil feed, where the de-asphalting column is in the absence of water; andwithdrawing a de-asphalted oil from the de-asphalting column, where the de-asphalted oil is in the absence of the heteropolyacids, where the de-asphalted oil has a lower concentration of sulfur, a lower concentration of nitrogen, and a lower concentration of metals as compared to the oil feed, where the process for ...

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Номер записи: 87
02-04-2020 дата публикации

METHOD AND APPARATUS FOR PREVENTING COKE FORMATION IN THE REACTOR VAPOR FEED NOZZLE OF A FLUID CATALYTIC CRACKING UNIT (FCCU) MAIN FRACTIONATOR COLUMN

Номер: US20200102512A1
Автор: BARLETTA, GOLDEN Scott William, JR. Anthony Frederick, NICCUM Grant Joseph
Принадлежит:

The present disclosure generally relates to method and apparatus for preventing coke formation in reactor vapor feed nozzle of a fractionator column of a fluid catalytic cracking unit. One or more baffles are positioned within the fractionator column to prevent effluent vapor that is directed by the reactor vapor feed nozzle into the feed zone from flowing back into the reactor vapor feed nozzle. The reactor vapor feed nozzle itself, or an internal nozzle coupled to the reactor vapor feed nozzle, may extend at least partially into the feed zone to similarly act as a baffle. 1. A method for preventing coke formation in a fluid catalytic cracking unit , comprising:receiving an effluent vapor from a reactor into a fractionator;flowing the effluent vapor to a feed zone of the fractionator via a reactor vapor feed nozzle; andblocking effluent vapor condensation from entering the reactor vapor feed nozzle, thereby preventing coke formation in the reactor vapor feed nozzle.2. The method of claim 1 , wherein a pair of baffles coupled to the fractionator and oriented vertically at a circumferential distance from the reactor vapor feed nozzle block the effluent vapor condensation from entering the reactor vapor feed nozzle.3. The method of claim 2 , wherein the pair of baffles are oriented perpendicular to a tangential line of an outer circumference of the fractionator.4. The method of claim 2 , wherein each baffle is positioned such that a top end of the baffle is positioned higher than a top end of the reactor vapor feed nozzle claim 2 , and such that a bottom end of the baffle is positioned lower than a bottom end of the reactor vapor feed nozzle.5. The method of claim 2 , wherein each baffle is positioned such that a longitudinal axis of the baffle forms an angle relative to a center point of the fractionator along a radial line claim 2 , the angle ranging from about 0 degrees to about 45 degrees.6. The method of claim 1 , wherein a pair of baffles coupled to the ...

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Номер записи: 88
02-04-2020 дата публикации

ASPHALTENE-INHIBITING AROMATIC POLYMER COMPOSITIONS

Номер: US20200102513A1
Автор: Braden Michael L., Dhawan Ashish, Gul Omer
Принадлежит:

The present invention generally relates to nonylphenol-free alkoxylated 4-(alkyloxy)phenol/aldehyde resins and processes for making alkoxylated 4-(alkyloxy)phenol/aldehyde resins. The invention also relates to methods of breaking emulsions of oil and water comprising the dosing of an effective amount of an emulsion breaker composition into a stable emulsion to destabilize the emulsion, wherein the emulsion breaker composition comprises an alkoxylated 4-(alkyloxy)phenol/aldehyde resin. 2. The method of claim 1 , wherein the asphaltene is further inhibited from deposition.4. The method of claim 3 , wherein Ris C-Calkyl.5. (canceled)6. The method of claim 3 , wherein Ris C-Calkyl.7. (canceled)8. The method of claim 3 , wherein Ris C-Calkyl.9. (canceled)10. The method of claim 3 , wherein Ris octyl.11. The method of claim 3 , wherein Rand Rare independently hydrogen or Cto Calkyl.12. (canceled)13. The method of claim 3 , wherein Rand Rare independently hydrogen or methyl.14. The method of claim 3 , wherein Rand Rare hydrogen.15. The method of claim 3 , wherein Ris hydrogen claim 3 , methyl claim 3 , butyl claim 3 , or benzyl.16. The method of claim 15 , wherein Ris methyl.17. The method of claim 15 , wherein Ris hydrogen.1819.-. (canceled)20. The method of claim 3 , wherein the polymer has a weight average molecular weight of from about 500 Daltons to about 25 claim 3 ,000 Daltons.21. The method of claim 3 , wherein the polymer has a weight average molecular weight of from about 2000 Daltons to about 10 claim 3 ,000 Daltons.22. The method of claim 3 , wherein the asphaltene-inhibiting composition comprises from about 10 wt. % to about 90 wt. % of the polymer corresponding in structure to Formula 1 and the balance being a hydrophobic solvent.23. The method of claim 22 , wherein the hydrophobic solvent comprises toluene claim 22 , xylene claim 22 , an ethylbenzene claim 22 , an aromatic naphtha claim 22 , a produced hydrocarbon claim 22 , diesel claim 22 , kerosene claim ...

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Номер записи: 89
30-04-2015 дата публикации

Preventing equipment fouling via corrosion reduction

Номер: US20150118398A1
Автор: Benjamin Edward Niemaseck, John Richardson, Mark Jason Puchovich, Robert Wright BEDINGER III
Принадлежит: ChemTreat Inc

An embodiment prevents equipment fouling (deposition of unwanted material) in an oil recovery system via implementing passivation of metallic components. By preventing or at least slowing or inhibiting corrosion of equipment or components via passivation, such as passivating heat exchangers, metallic piping, and the like, an embodiment in turn reduces fouling thereof. Other embodiments are described and claimed.

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Номер записи: 90
18-04-2019 дата публикации

DEVICE COMPRISING LATERAL INJECTIONS OF LIQUID FOR LIMITING THE PHENOMENA OF SOLID DEPOSITS IN ITEMS OF EQUIPMENT WITH A CONICAL BOTTOM

Номер: US20190112536A1
Автор: AMBLARD Benjamin, LE COZ Jean-Francois, MARQUES Joao
Принадлежит: IFP ENERGIES NOUVELLES

A device for the descending flow of a hydrocarbon-containing liquid containing solid particles at the bottom of an item of equipment () and a process for the conversion of hydrocarbon-containing feedstocks implementing said device. 111111292. Device for the descending flow of a hydrocarbon-containing liquid containing solid particles at the bottom of an item of equipment () comprising a cylindrical upper part () of diameter D , a truncated-cone-shaped lower part () with an angle of inclination a comprised between 5° and 85° with respect to the vertical axis (z) of said cylindrical upper part , an outlet pipe () of diameter D , characterized in that it comprises:{'b': 5', '12', '1, 'at least one injection () of recycled and/or makeup liquid into the truncated-cone-shaped part () of the item of equipment ();'}{'b': 6', '11', '1, 'at least one injection () of recycled and/or makeup liquid into the cylindrical part () of the item of equipment ();'}{'b': 5', '1', '2', '6', '1', '2', '1', '1', '2', '2, 'said injection or injections () situated in said truncated-cone-shaped part being inclined with respect to the wall of the truncated-cone-shaped lower part at an angle β in the vertical plane (xz) and at an angle β in the horizontal plane (xy); said injection or injections () situated in said cylindrical part being inclined with respect to the wall of the cylindrical upper part at an angle θ in the vertical plane (xz) and at an angle θ in the horizontal plane (xy), the angles β and θ being comprised between 5° and 175°, the angles β and θ being comprised between 90° and 270°.'}249456. Device according to comprising a pipe () for recycling a part of the liquid leaving said outlet pipe () claim 1 , said recycling pipe () supplying recycled liquid to at least one of said injections () or ().31056. Device according to comprising a makeup pipe () for supplying makeup liquid to at least one of said injections () or ().478. Device according to in which said injections are ...

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Номер записи: 91
03-05-2018 дата публикации

SULFUR REMOVAL FROM PETROLEUM FLUIDS

Номер: US20180119028A1
Автор: COLLETT Terry L., MISBAH Aatif A., XIN Mei
Принадлежит: CABOT CORPORATION

A method for removing sulfur containing compounds from petroleum liquid. The method includes contacting the petroleum liquid with an activated carbon that has a high ash content, a high metal content and a significant amount of meso and macro porosity. 1. A method of removing sulfur compounds from petroleum liquid , the method comprising:contacting a petroleum liquid with activated carbon, the petroleum liquid comprising at least one sulfur containing compound, the activated carbon having an ash content of greater than 20% by weight and a metal content of greater than 2,000 ppm by weight; andremoving greater than 90% of the sulfur compounds originally in the petroleum liquid to provide a reduced sulfur petroleum liquid.2. The method of wherein the petroleum liquid claim 1 , prior to contacting claim 1 , comprises greater than 1% sulfur by weight.3. The method of wherein the petroleum liquid comprises hydrogen sulfide of which at least 90% by weight is removed by contacting with the activated carbon.4. (canceled)5. The method of wherein contacting comprises flowing the petroleum liquid through one or more beds of the activated carbon.6. (canceled)7. (canceled)8. The method of wherein the petroleum liquid comprises mercaptans of which at least 90% by weight are removed from the liquid by contacting the liquid with the activated carbon.9. The method of wherein the total sulfur concentration is reduced to less than 10 μg/g.10. A method comprising:determining the concentration of sulfur or a sulfur containing compound in a petroleum liquid stream;identifying the stream as requiring removal of sulfur or a sulfur containing compound;contacting the petroleum liquid with an activated carbon, the activated carbon having an ash content of greater than 20% and a metal content of greater than 2,000 ppm; andreducing the sulfur content of the petroleum liquid to less than 10 ppm total sulfur or less than 10 ppm of the sulfur containing compound.11. The method of wherein the ...

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Номер записи: 92
03-05-2018 дата публикации

CORROSION INHIBITOR FORMULATIONS

Номер: US20180119289A1
Автор: Hatchman Kevan
Принадлежит:

The instant invention relates to a corrosion inhibitor composition that contains: (a) at least one biodegradable polyhydroxyacid and/or polyhydroxylated derivative thereof, preferably a polyhydroxyacid that may be in all or part in the form a polyhydroxylated salt and/or a polyhydroxyamide; and (b) a biodegradable cationic compound having a molecular weight of less than 500 Da, preferably between 50 and 400 Da 1. A corrosion inhibitor composition comprising:(a) at least one biodegradable polyhydroxyacid and/or polyhydroxylated derivative thereof; and(b) a biodegradable cationic compound having a molecular weight of less than 500 Da.2. The composition of claim 1 , wherein the biodegradable polyhydroxyacid and/or polyhydroxylated derivative thereof (a) is selected from the group consisting of:biodegradable polyhydroxy acids;metal salts of such biodegradable polyhydroxy acids;alkanolamine salts of such biodegradable polyhydroxy acids;polyhydroxy amides obtainable by reaction of alkanolamines with such biodegradable polyhydroxy acids; andmixtures thereof.3. The composition of claim 2 , wherein the biodegradable polyhydroxyacid and/or polyhydroxylated derivative thereof (a) is gluconic acid.4. The composition of claim 1 , wherein the biodegradable cationic compound (b) is:a choline salt (choline being trimethyl (2-hydroxyethyl) ammonium hydroxide);{'sub': 1', '3', '1', '3, 'a (C-Calkyl)trimethylammonium or di(C-Calkyl) dimethylammonium salt;'}{'sub': 1', '3, 'a dihydroxy tri(C-Calkyl) ammonium halide or dihydroxy tri(C1-C3 hydroxyalkyl) ammonium halide;'}{'sub': 1', '3, 'a cationic compound as obtained by the hydrolysis of chlorohydroxalkyl tri(C-Calkyl or hydroxalkyl) ammonium salts; or'}a mixture of two or more of said salts.5. The composition of claim 4 , wherein the biodegradable cationic compound (b) is a choline salt.6. The composition of claim 1 , further comprising:(c) an antioxidant.7. The composition of claim 1 , further comprising:(d) a pH buffer.8. The ...

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Номер записи: 93
25-04-2019 дата публикации

REMOVAL OF KINETIC HYDRATE INHIBITORS

Номер: US20190118114A1
Автор: Al-Adel Shadi I., Mohammad Ahmad Fadzil, Rithauddeen Megat A.
Принадлежит: Saudi Arabian Oil Company

A method includes receiving a water stream from a hydrocarbon production facility, the water stream having a first concentration of a kinetic hydrate inhibitor (KHI); flowing the water stream through a heat exchanger to heat the water stream to a target temperature; mixing the heated water stream with a treatment chemical to form a two-phase mixture, the treatment chemical having an affinity for the KHI; flowing the two-phase mixture into a separator; and physically separating the two-phase mixture into a first phase and a second phase, the first phase including water and having a second concentration of the KHI less than the first concentration, and the second phase including the KHI and the treatment chemical, the density of the second phase being less than the density of the first phase. 1. A method comprising:receiving a water stream from a hydrocarbon production facility, the water stream having a first concentration of a kinetic hydrate inhibitor (KHI);flowing the water stream through a heat exchanger to heat the water stream to a target temperature;mixing the heated water stream with a treatment chemical to form a two-phase mixture, the treatment chemical having an affinity for the KHI;flowing the two-phase mixture into a separator; andphysically separating the two-phase mixture into a first phase and a second phase, the first phase including water and having a second concentration of the KHI less than the first concentration, and the second phase including the KHI and the treatment chemical, the density of the second phase being less than the density of the first phase.2. The method of claim 1 , wherein receiving the water stream comprises:receiving a fluid stream from the hydrocarbon production facility; andseparating the fluid stream into a hydrocarbon stream and the water stream.3. The method of claim 2 , further comprising separating the fluid stream into the hydrocarbon stream claim 2 , the water stream claim 2 , and a gas stream.4. The method of claim ...

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Номер записи: 94
25-04-2019 дата публикации

DECREASING FOULANT DEPOSITION ON AT LEAST ONE SURFACE BY CONTACTING THE SURFACE(S) WITH AT LEAST ONE PROTEIN

Номер: US20190119554A1
Автор: Armstrong Charles David, Dhulipala Prasad D.
Принадлежит: Baker Hughes, a GE company, LLC

Corrosion and/or calcium scale deposition on a surface in contact with corrosion forming components and/or scale forming components within a subterranean formation may be decreased, prevented, and/or inhibited by contacting the surface with at least one protein. The protein(s) may be or include, but is not limited to, at least one aspein protein, at least one aspolin protein, at least one dentine protein, at least one DRICH-1 protein, at least one nacrein protein, at least one SMDT-1 protein, derivatives thereof, fragments thereof, mimetics thereof, and combinations thereof. The surface may be or include, but is not limited to a metal surface, a plastic surface, a ceramic surface, a painted surface, a coated surface, and combinations thereof. 1. A fluid composition comprising:a base fluid selected from the group consisting of a drilling fluid, a completion fluid, a production fluid, a servicing fluid, an injection fluid, a refinery fluid, and combinations thereof;an additive composition comprising at least one protein selected from the group consisting of at least one aspein protein, at least one aspolin protein, at least one dentine protein, at least one DRICH-1 protein, at least one nacrein protein, at least one SMDT-1 protein, derivatives thereof, fragments thereof, mimetics thereof, and combinations thereof.2. The fluid composition of claim 1 , wherein the at least one protein is selected from the group consisting of at least one aspein protein and at least one aspolin protein claim 1 , further wherein:the at least one aspein protein comprises an amino acid sequence that is at least 75% homologous to the amino acid sequence of SEQ ID NO:1;the at least one aspolin protein comprises an amino acid sequence that is at least 75% homologous to the amino acid SEQ ID:2, the amino acid SEQ ID:3, and combinations thereof; andcombinations thereof.3. The fluid composition of claim 1 , wherein the at least one protein is selected from the group consisting of natural proteins ...

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Номер записи: 95
25-04-2019 дата публикации

Decreasing foulant deposition on at least one surface by contacting the surface(s) with at least one protein

Номер: US20190119555A1
Автор: Charles David Armstrong, Prasad D. DHULIPALA
Принадлежит: Baker Hughes Inc

Corrosion and/or calcium scale deposition on a surface in contact with corrosion forming components and/or scale forming components within a subterranean formation may be decreased, prevented, and/or inhibited by contacting the surface with at least one protein. The protein(s) may be or include, but is not limited to, at least one aspein protein, at least one aspolin protein, at least one dentine protein, at least one DRICH-1 protein, at least one nacrein protein, at least one SMDT-1 protein, derivatives thereof, fragments thereof, mimetics thereof, and combinations thereof. The surface may be or include, but is not limited to a metal surface, a plastic surface, a ceramic surface, a painted surface, a coated surface, and combinations thereof.

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Номер записи: 96
16-04-2020 дата публикации

SUPERCRITICAL REACTOR SYSTEMS AND PROCESSES FOR PETROLEUM UPGRADING

Номер: US20200115639A1
Автор: Al-Abdullah Mohammad A., Alabdulhadi Abdullah T., Choi Ki-Hyouk
Принадлежит: Saudi Arabian Oil Company

Provided herein are supercritical upgrading reactors and reactor systems for upgrading a petroleum-based composition by using one or more supercritical upgrading reactors and one or more supercritical standby reactors that alternate functions such that the supercritical upgrading reactor is converted to a supercritical standby reactor and the supercritical standby reactor is converted to a supercritical upgrading reactor. The supercritical upgrading reactor upgrades a combined feed stream while a supercritical standby reactor delivers a cleaning fluid into the supercritical standby reactor. The supercritical reactors may have one or more catalyst layers and one or more purging fluid inlets, and the catalyst layers may have differing void volume ratios. 1. A process for upgrading a petroleum-based composition comprising:combining a supercritical water stream with a pressurized, heated petroleum-based composition in a mixing device to create a combined feed stream,introducing the combined feed stream into an upgrading reactor system comprising one or more supercritical upgrading reactors and one or more supercritical standby reactors,where the supercritical upgrading reactor and the supercritical standby reactor both operate at a temperature greater than a critical temperature of water and a pressure greater than a critical pressure of water,where the supercritical upgrading reactor and the supercritical standby reactor both comprise at least one catalyst layer, andupgrading the combined feed stream in the supercritical upgrading reactor to produce an upgraded product;cleaning the supercritical standby reactor by passing a cleaning fluid into the supercritical standby reactor, while the upgrading step is being performed in the supercritical upgrading reactor; andalternating functions of the supercritical upgrading reactor and the supercritical standby reactor, such that the supercritical upgrading reactor is converted to a supercritical standby reactor undergoing a ...

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Номер записи: 97
27-05-2021 дата публикации

Non-Solvent Crude Oil Heavy Oil Stream De-Asphalting Process

Номер: US20210155857A1
Автор: Shaikh Sohel K, SUN Miao, Zhang Zhonglin
Принадлежит: Saudi Arabian Oil Company

A process for removing asphaltenes from an oil feed, the process comprising the steps of introducing the oil feed to a de-asphalting column, where the oil feed comprises a carbonaceous material and asphaltenes, where the de-asphalting column comprises a heteropolyacid, operating the de-asphalting column at a reaction temperature and a reaction pressure for a residence time such that the heteropolyacid is operable to catalyze an acid catalyzed polymerization reaction of the asphaltenes to produce polymerized asphaltenes, the polymerized asphaltenes precipitate from the carbonaceous material in the oil feed, and withdrawing a de-asphalted oil from the de-asphalting column, where the de-asphalted oil is in the absence of the heteropolyacids, where the de-asphalted oil has a lower concentration of sulfur, a lower concentration of nitrogen, and a lower concentration of metals as compared to the oil feed, where the process for removing asphaltenes is in the absence of added hydrogen gas. 1. A system for removing asphaltenes from an oil feed , the system comprising:a de-asphalting column, the de-asphalting column configured to operate at a reaction pressure, a reaction temperature, and for a residence time such that an acid catalyzed polymerization reaction of asphaltenes in the oil feed occurs to produce a polymerized asphaltenes, where the de-asphalting column is in the absence of water, where the de-asphalting column comprises a heteropolyacid; andan evaporator fluidly connected to the de-asphalting column, the evaporator configured to separate the polymerized asphaltenes from a solvent to produce a cleaned solvent stream and a recovered asphaltenes, where the recovered asphaltenes comprises the polymerized asphaltenes.2. The system of claim 1 , further comprising an upgrading reactor fluidly connected to the separator claim 1 , the upgrading reactor configured to upgrade the de-asphalted oil.3. The system of claim 1 , where the heteropolyacid is selected from the group ...

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Номер записи: 98
27-05-2021 дата публикации

HEAVY AROMATIC SOLVENTS FOR CATALYST REACTIVATION

Номер: US20210155858A1
Автор: Hodgkins Robert Peter, KOSEOGLU Omer Refa
Принадлежит: Saudi Arabian Oil Company

Compositions and methods for restoring catalytic activity by dissolving soft coke with a solvent, one method including detecting soft coke deposition on a catalyst composition; preparing an aromatic bottoms composition with a Hildebrand solubility parameter of at least about 20 SI to remove the soft coke from the catalyst composition; and washing the catalyst composition with the aromatic bottoms composition until at least a portion of the soft coke deposition is removed. 1. A method for restoring catalytic activity by dissolving soft coke with a solvent , the method comprising the steps of:detecting soft coke deposition on a catalyst composition;preparing an aromatic bottoms composition with a Hildebrand solubility parameter of at least about 20 (SI) to remove the soft coke from the catalyst composition; andwashing the catalyst composition with the aromatic bottoms composition until at least a portion of the soft coke deposition is removed.2. The method according to claim 1 , where the step of detecting soft coke deposition on the catalyst composition comprises detecting a pressure drop increase over a catalyst bed comprising the catalyst composition of at least about 1 bar.3. The method according to claim 1 , where the step of detecting soft coke deposition on the catalyst composition comprises detecting a radial temperature profile change in a reactor of at least about 1° C.4. The method according to claim 1 , where the aromatic bottoms composition comprises aromatic bottoms from an aromatic recovery complex.5. The method according to claim 1 , where the aromatic bottoms composition comprises aromatic bottoms from a xylene rerun column of an aromatic recovery complex.6. The method according to claim 1 , where the aromatic bottoms composition consists essentially of aromatic bottoms from a xylene rerun column of an aromatic recovery complex.7. The method according to claim 1 , where the aromatic bottoms composition consists of aromatic bottoms from a xylene rerun ...

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Номер записи: 99
11-05-2017 дата публикации

METHOD AND KIT FOR TREATMENT OF COMPONENTS UTILIZED IN A CRUDE OIL SERVICE OPERATION

Номер: US20170130145A1
Автор: Brashear Brian Keith, DREES SEAN ERIC, Hanson Eric, Hughes Edward, MARZEC ANDREW TIMOTHY
Принадлежит:

A method and kit for treatment of a stainless steel or other nickel alloy component utilized in a crude oil service operation including cleaning a surface of the component to remove surface contamination; drying the cleaned surface of the component; applying a coat of Self-Assembled Monolayer of Phosphonate (SAMP) to the cleaned and dried surface of the component to form a treated component; and installing the treated component into a section of a crude oil service operation. The coating reduces paraffin/asphaltene deposition on the component. The kit includes a cleaner wipe impregnated with a cleaning substance for cleaning the component; a nano-coating wipe impregnated with a SAMP for applying a nano-coating of the SAMP to the component; and instructions for treating said component utilizing the cleaner wipe and the nano-coating wipe. 1. A method for treatment of a controller or sensor component utilized in a crude oil service operation comprising the steps of: cleaning a surface of said component to remove surface contamination , wherein said controller or sensor component is of a stainless steel or other nickel alloy composition; drying said cleaned surface of said component; applying a coat of a Self-Assembled Monolayer of Phosphonate (SAMP) composition within a glycol carrier to said cleaned and dried surface of said component to form a treated component; and installing said treated component into a section of a crude oil service operation , said coating reducing paraffin/asphaltene deposition on said component.2. The method of wherein said applying step yields a nano-coating of said SAMP composition which permanently changes the molecular characteristics of said surface of said component.3. The method of wherein said section of said oil service operation wherein said component is installed has a low acidity liquid portion.4. The method of wherein said section of said oil service operation wherein said component is installed has a low turbulence portion.5. The ...

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Номер записи: 100