УМЕНЬШЕНИЕ ОТЛОЖЕНИЙ ПРИ ФРАКЦИОНИРОВАНИИ БЕНЗИНА, В СИСТЕМЕ ВОДЯНОГО ОХЛАЖДЕНИЯ И СЕКЦИИ ИЗВЛЕЧЕНИЯ ПРОДУКТА

Изобретение относится к способу выбора растворителя или смеси растворителей, применимых для уменьшения образования отложений, очистки от существующих отложений и/или снижения скорости формирования отложений. Изобретение касается способа диспергирования загрязняющих примесей в потоке жидких углеводородов, причем способ включает стадии, на которых определяют природу загрязняющих примесей в потоке жидких углеводородов путем измерения величины потока жидкого углеводорода и оценки отношения водорода к углероду в потоке жидкого углеводорода на основании измеренного значения; выбирают растворитель или смесь растворителей, пригодные для диспергирования загрязняющих примесей, на основе определения их природы, причем отношение водорода к углероду выбранного растворителя, или смеси растворителей, меньше, чем оцененное отношение водорода к углероду в потоке жидкого углеводорода; и обеспечивают контактирование загрязняющих примесей с выбранными растворителем или смесью растворителей. Технический результат ...

СПОСОБ ПЕРЕРАБОТКИ ГАЗООБРАЗНЫХ АЛКАНОВ

Изобретение относится к способу переработки газообразных алканов путем воздействия ионизирующим излучением на содержащую их сырьевую смесь с получением продуктов радиолиза, в процессе которого из продуктов радиолиза постоянно удаляют водород и конденсируемую фракцию, являющуюся целевым продуктом, а оставшуюся часть смешивают с исходной смесью, содержащей алканы, с получением сырьевой смеси, характеризующемуся тем, что воздействие ионизирующим излучением осуществляют при температуре реакционной смеси не ниже минимальной температуры конденсации низших спиртов и эфиров и не выше 350°С. Использование настоящего способа обеспечивает возможность использования как искусственных, так и природных многокомпонентных смесей углеводородов с естественными примесями (природного и попутного нефтяного газа, широкой фракции легких углеводородов и др., без глубокой очистки); расширение ассортимента конечных продуктов за счет возможности получения качественного дизельного топлива, пропан-бутановых, бутан-пентановых ...

СПОСОБ УМЕНЬШЕНИЯ КОНЦЕНТРАЦИИ РАСТВОРИМЫХ В ВОДЕ КАРБОНОВЫХ КИСЛОТ

... 1. Способ уменьшения концентрации растворимых в воде карбоновых кислот в углеводородной смеси, который включает:(i) отбор образца из углеводородной смеси и экстрагирование растворимых в воде карбоновых кислот из образца,(ii) проведение для экстрагированных растворимых в воде карбоновых кислот исследования по методу хроматографии,(iii) вычисление концентрации растворимых в воде карбоновых кислот в углеводородной смеси на основании результатов хроматографии и(iv) уменьшение концентрации растворимых в воде карбоновых кислот в углеводородной смеси исходя из рассчитанной концентрации растворимых в воде карбоновых кислот в углеводородной смеси.2. Способ по п.1, в котором концентрацию карбоновых кислот уменьшают до менее чем 1 ч./млн. (мас.).3. Способ по п.1, в котором углеводородная смесь представляет собой сырую нефть и/или конденсат.4. Способ по п.1, в котором углеводородная смесь дополнительно содержит воду.5. Способ по п.1, в котором стадию (i) проводят путем твердофазного экстрагирования ...

ПРИМЕНЕНИЕ ИНСТРУМЕНТАЛЬНЫХ СРЕДСТВ АНАЛИЗА УСТАНОВКИ ВИСБРЕКИНГА ДЛЯ ОПТИМИЗАЦИИ РАБОЧИХ ХАРАКТЕРИСТИК

... 1. Способ уменьшения и оптимизации скорости загрязнения в технологической установке, включающий следующие шаги:оценку концентрации загрязняющих материалов, содержащихся в текучей среде технологической установки;определение потенциала загрязнения на основе упомянутой концентрации;определение воздействия химиката, предохраняющего от загрязнения, на потенциал загрязнения в установке;определение приемлемого базового потенциала загрязнения;сравнение упомянутого базового параметра с концентрацией загрязняющих материалов, измеренной во время последующей работы установки; ирегулирование ввода упомянутого химиката, предохраняющего от загрязнения, в технологическую установку во время работы установки на основании упомянутого сравнения для достижения одной или более целей установки.2. Способ по п.1, в котором упомянутые цели установки включают улучшенный выход, улучшенное качество и уменьшение технического обслуживания, связанного с загрязнением.3. Способ по п.2, в котором упомянутый шаг оценки включает ...

СПОСОБ И СИСТЕМА РАБОТЫ ПЕЧИ ПОЛУЧЕНИЯ ЭТИЛЕНА

VERFAHREN ZUM ERHITZEN VON KOHLENWASSERSTOFFEN IN GEGENWART NICKELEISENHALTIGER METALLFLAECHEN

Extraction of hydrocarbons from hydrocarbon-containing materials and/or processing of hydrocarbon-containing materials.

Inhibiting corrosion and scaling of surfaces contacted by sulfur-containing materials.

EXTRACTION OF HYDROCARBONS FROM HYDROCARBON-CONTAINING MATERIALS AND/OR PROCESSING OF HYDROCARBON-CONTAINING MATERIALS

Inhibiting corrosion and scaling of surfaces by sulfur-containing materials

Inhibiting corrosion and scaling of surfaces contacted by sulfur-containing materials.

Extraction of hydrocarbons from hydrocarbon-containing materials and/or processing of hydrocarbon-containing materials.

Inhibiting corrosion and scaling of surfaces contacted by sulfur-containing materials.

Extraction of hydrocarbons from hydrocarbon-containing materials and/or processing of hydrocarbon-containing materials.

HIGH-TEMPERATURE CORROSION INHIBITOR

Acoustic agglomeration to reduce fouling in thermal conversion

Use of polyester polyamine and polyester polyquaternary ammonium compounds as corrosion inhibitors

The present invention relates to the use of a polyesteramine or a polyester polyquaternary ammonium compound as a corrosion inhibitor for metal surfaces, and to a method for protecting a metal surface from corrosion by contacting the metal surface with said corrosion inhibitor.

STRUCTURAL MATERIAL FOR HYDROCARBON PROCESSING PLANT

Polyester polyamine and polyester polyquaternary ammonium corrosion inhibitors

The present invention relates to the use of a product obtainable by the reaction of a fatty acid, or mixture of acids, having the formula R ...

METHOD TO MITIGATE FOULING IN A HYDROCARBON PLANT

Described herein are systems and methods of fouling mitigation in a hydrocarbon fractionation column. The methods correlate operating parameters of the fractionation column, specifically flow rate and temperature, with fouling. The methods can include measuring a temperature and a flow rate at a bottom stream of the hydrocarbon fractionation column; providing the measured temperature and flow rate to a processing device; determining, by the processing device, based on the measured temperature and flow rate of the bottom stream, an antifoulant treatment protocol for the hydrocarbon fractionation column; and treating the hydrocarbon fractionation column by controlling, by the processing device, a feed control unit in accordance with the determined antifoulant treatment protocol.

METHOD OF REDUCING CORROSION IN A CRUDE UNIT

ACOUSTIC AGGLOMERATION TO REDUCE FOULING IN THERMAL CONVERSION PROCESSES

This invention relates to a process for reducing fouling of equipment used in thermal conversion processes such as FLUID COKING~ and FLEXICOKING~. Acoustic energy is used to acoustically agglomerate fine mists created during the coking process. The agglomerated mists are then carried along with the circulating coke instead of depositing on coking equipment.

A NOVEL ADDITIVE FOR NAPHTHENIC ACID CORROSION INHIBITION AND METHOD OF USING THE SAME

The present invention relates to the field of processing hydrocarbons which causes corrosion in the metal surfaces of processing units. The invention addresses the technical problem of high temperature naphthenic acid corrosion and sulphur corrosion and provides a solution to inhibit these types of corrosion. The three combination compositions are formed by two mixtures separately, with one mixture obtained by mixing compound A, which is obtained by reacting high reactive polyisobutylene (HRPIB) with phosphorous pentasulphide in presence of catalytic amount of sulphur with compound B which is thiophosphorous compound such as phosphorous thioacid ester of Formula (1) and second mixture obtained by mixing compound A with compound C of Formula (2) which is obtained by reacting compound B with ethylene oxide, wherein each of these two mixtures independently provide high corrosion inhibition efficiency in case of high temperature naphthenic acid corrosion inhibition and sulphur corrosion inhibition ...

ADDITION OF HIGH MOLECULAR WEIGHT NAPHTHENIC TETRA-ACIDS TO CRUDE OILS TO REDUCE WHOLE CRUDE OIL FOULING

High molecular weight naphthenic tetra-acids are added to a base crude oil to prevent and/or reduce fouling of crude oil refinery equipment. The method includes adding an effective amount of a high molecular weight naphthenic tetra-acid to the base crude oil to form a crude oil mixture and feeding the crude oil mixture to a crude oil refinery component. Particularly, the high molecular weight naphthenic tetra- acids include ARN acids.

STRONG BASE AMINES TO MINIMIZE CORROSION IN SYSTEMS PRONE TO FORM CORROSIVE SALTS

Corrosion by ammonia/amine salts in hydrocarbon streams such as distillation overhead streams that contain a mineral acid and water can be prevented, avoided or minimized by adding certain strong amines to the streams. The amines have a pKa between about 1 0.5 to about 12 and include, but are not necessarily limited to, dimethylamine, diethylamine, dipropylamine, diisopropylamine, di-n-butylamine, diisobutylamine, di-sec-butylamine, di-tert- butylamine, pyrrolidine, piperidine, and combinations thereof. If the hydrocar¬ bon stream further includes a nitrogen-containing compound such as ammonia, a tramp and/or a residual amine which can form a corrosive salt with the mineral acid, then the added amine is a stronger base than the tramp or residual amine, if present. The amount of added amine is greater than total amount of nitrogen-containing compound, so that any corrosive salts formed are less corrosive than the salts that would otherwise form from the ammonia and/or tramp amine.

POLYESTER POLYAMINE AND POLYESTER POLYQUATERNARY AMMONIUM CORROSION INHIBITORS

The present invention relates to the use of a product obtainable by the reaction of a fatty acid, or mixture of acids, having the formula R1COOH (I); and a dicarboxylic acid or a derivative thereof having the formula (IIa) or (IIb) with an alkoxylated fatty amine having the formula (III) or a partial or wholly quaternised derivative thereof; optionally said reaction between the fatty acid, the dicarboxylic acid and the alkoxylated fatty amine is being followed by a further reaction step wherein part or all of the nitrogen atoms are quaternised by reaction with an alkylating agent R5X; as a corrosion inhibitor for metal surfaces. The present invention also relates to such products and to methods for their production.

METHOD AND APPARATUS FOR REDUCING FOULING USING RESID FRACTIONS OF HIGH TAN AND HIGH SBN CRUDE OIL

Atmospheric and/or vacuum resid fractions of a high solvency dispersive power (HSDP) crude oil are added to a blend of crude oil to prevent fouling of crude oil refinery equipment and to perform on-line cleaning of fouled refinery equipment. The HSDP resid fractions dissolve asphaltene precipitates and maintain suspension of inorganic particulates before coking affects heat exchange surfaces.

PROCESS FOR CONVERTING A SOLID BIOMASS MATERIAL

A process for converting a solid biomass material, comprising contacting the solid biomass material with a catalytic cracking catalyst at a temperature of more than 400°C in a riser reactor to produce one or more cracked products, wherein the riser reactor is an internal riser reactor.

METHOD OF REFORMING OF HYDROCARBONS

ПОДАВЛЕНИЕ КОРРОЗИИ И ОБРАЗОВАНИЯ ОКАЛИНЫ НА ПОВЕРХНОСТЯХ, КОНТАКТИРУЮЩИХ С СЕРОСОДЕРЖАЩИМИ МАТЕРИАЛАМИ

В заявке описан способ обработки для подавления коррозии или образования окалины, обусловленных присутствием серы, или для удаления окалины с поверхности, включая подавление коррозии, вызванной серосодержащими материалами, уменьшение коррозии, вызванной серосодержащими материалами, подавление образования окалины, вызванного присутствием серы и серосодержащими материалами в газообразной, жидкой или твердой фазе или любой комбинацией многочисленных фаз материалов, уменьшение окалины, образование которой вызвано присутствием серы и серосодержащими материалами, а также удаление окалины, образование которой вызвано присутствием серы и серосодержащими материалами. Способ заключается в том, что серосодержащие материалы контактируют с композицией, включающей терпентиновую жидкость. Способ также заключается в том, что корродируемые поверхности или поверхности, предрасположенные к образованию окалины, контактируют с композицией, включающей терпентиновую жидкость.

EXTRACTION OF HYDROCARBONS FROM HYDROCARBON-CONTAINING MATERIALS AND/OR PROCESSING OF HYDROCARBON-CONTAINING MATERIALS

ПОЛИМЕРНЫЕ ИНГИБИТОРЫ КОРРОЗИИ

Изобретение относится к использованию продукта, который можно получить по реакции алкоксилированного амина жирного ряда, имеющего формулу где R означает гидрокарбильную группу, содержащую 8-24 атома углерода; каждый из В независимо является алкильной группой, содержащей от 1 до 4 атомов углерода, бензильной группой или группой (AO)nH, где A является алкиленовой группой, содержащей 2-4 атома углерода, предпочтительно 2 атома углерода; каждый из n равен по меньшей мере 1, а сумма всех n равна 2-30; х равен 2 или 3; у равен 0-3, предпочтительно 0 или 1; или продукта, получаемого путем частичной или полной кватернизации продукта формулы (I); с производным двухосновной карбоновой кислоты, имеющим формулу где D означает -OH, -Cl или -OR3, где R3 означает алкильную группу С1-С4; R2 означает алкиленовый радикал формулы -(CH2)z-, где z - целое число от 1 до 10, предпочтительно от 2 до 4, наиболее предпочтительно 2, где алкиленовый радикал может быть замещен одной или двумя группами -ОН, группой ...

METHOD OF REFORMING HYDROCARBONS

INHIBITING CORROSION AND SCALING OF SURFACES CONTACTED BY SULFUR-CONTAINING MATERIALS

EXTRACTION OF HYDROCARBONS FROM HYDROCARBON-CONTAINING MATERIALS AND/OR PROCESSING OF HYDROCARBON-CONTAINING MATERIALS

HEAT RESISTANT ALLOY FOR CARBURIZATION RESISTANCE

METAL TUBE FOR THERMAL CRACKING REACTION

CORROSION RESISTANT MATERIAL FOR REDUCED FOULING, HEAT TRANSFER COMPONENT WITH IMPROVED CORROSION AND FOULING RESISTANCE, AND METHOD FOR REDUCING FOULING

This invention relates to the reduction of sulfidation or sulfidic corrosion and the reduction of depositional fouling in general and in particular the reduction of sulifidation/sulfidic corrosion and the reduction of depositional fouling in heat transfer components, which include but are not limited to heat exchangers, furnaces and furnace tubes located in refining facilities and petrochemical processing facilities and other components used for transporting or conveying process streams, which may be prone to fouling. In particular, the present invention relates to the reduction of corrosion and fouling associated with process streams. The present invention is directed to a method of reducing fouling in a heat transfer component, which combines the use of a corrosion resistant material having the desired surface roughness with the application of vibration, pulsation and internal turbulence promoters. © KIPO & WIPO 2009 ...

UPGRADED EBULLATED BED REACTOR WITH NO RECYCLE BUILDUP OF ASPHALTENES IN VACUUM BOTTOMS

Minimizing corrosion in a methanol-to-olefin effluent processing system

The present invention is directed toward reducing corrosion in a methanol-to-olefin (MTO) effluent processing system, and particularly in the condensate removal system thereof, by injecting a neutralization agent into one or more target regions of the MTO effluent processing system. The neutralization agent ensures that any localized condensation in the MTO effluent processing system, particularly in the condensate removal system, occurs under basic conditions and that any acidic condensable components are neutralized. The invention is also directed to monitoring corrosion in an MTO effluent processing system and to monitoring the pH of localized corrosion sites in order to ensure proper neutralization of any acidic condensation formed therein.

METHOD AND APPARATUS FOR ESTERIFYING FATTY ACID

A method of esterifying free fatty acid in natural oil comprises heating the natural oil (2) to a first temperature above a reaction temperature, feeding the heated natural oil into an acid-resistant pipe reactor (5), providing a mixture of acid catalyst (6) and short chain alcohol (8) at a second temperature below the reaction temperature, and feeding the mixture of acid catalyst and short chain alcohol into the natural oil in the pipe reactor (5). The short chain alcohol and free fatty acid react at the reaction temperature to form an ester.

Method of reducing corrosion and corrosion byproduct deposition in a crude unit

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.

ANTI-COKING PROCESS FOR PRODUCING OILS FROM WASTE RUBBER OR WASTE PLASTICS AND EQUIPMENT THEREOF, AND DECOKING MECHANISM OF OIL PRODUCING EQUIPMENT

An anti-coking process is provided for oiling the rubber or plastic waste, and it involves the pyrolysis process that comes with the emission of hot air to be mixed with the high-temperature hot air that is ready to be sent into pyrolysis device. The equipment described includes a return air pipeline being connected to the hot air outlet. Meanwhile, a coking cleaning device is also introduced to remove the coke residual on the pyrolysis device wall in the cracking process. This device consists of a scraper, which, through the role of weights, is able to work with the inside surface of the cracking device.

METHOD OF DISPERSING HYDROCARBON FOULANT IN HYDROCARBON PROCESSING FLUID

【課題】炭化水素処理プラントの塔、導管、管路、オーバーヘッドほかの金属表面に堆積する重油、タール類、アスファルテン類、多環芳香族炭化水素類、コークス、ポリマー類、軽油、酸化炭化水素、熱分解産物類等を含む炭化水素汚染物質を炭化水素処理装置から除去する方法を提供する。 【解決手段】高沸点でハロゲンを含まない、処理温度において水よりも大きな密度の水非混和有機溶剤と接触させて、炭化水素汚染物質を分散、溶解またはその粘性を低減させる。 【選択図】なし

СПОСОБ, ВКЛЮЧАЮЩИЙ ДЕАСФАЛЬТИЗАЦИЮ РАСТВОРИТЕЛЯМИ И ПЕРЕРАБОТКУ В ПСЕВДООЖИЖЕННОМ СЛОЕ ОСТАТОЧНЫХ ПРОДУКТОВ ПЕРЕГОНКИ ТЯЖЕЛЫХ СЫРЫХ НЕФТЕЙ, И УСТРОЙСТВО ДЛЯ ОСУЩЕСТВЛЕНИЯ СПОСОБА

Изобретение относится к способу для экономичной переработки остаточных продуктов перегонки тяжелых сырых нефтей, включающему стадии: а) подачи сырья - остатка после перегонки нефти при атмосферном давлении или в вакууме, причем 30-100% указанного сырья кипит выше 524°С, в устройство для деасфальтизации растворителями SDA, с получением потока асфальтенов и потока деасфальтизата DAO; b) переработки указанного потока асфальтенов, по меньшей мере, в одном реакторе с псевдоожиженным слоем в присутствии катализатора, где реактор эксплуатируют при общем давлении от 10,335 до 20,670 кПа, температуре 399-454°С, удельном часовом расходе жидкости от 0,1 до 1,0 ч-1 и скорости замены катализатора от 0,285 до 2,85 кг/м3 или где реактор или реакторы эксплуатируют при общем давлении от 3445 до 20,670 кПа, температуре 388-438°С, удельном часовом расходе жидкости от 0,2 до 1,5 ч-1 и скорости замены катализатора от 0,142 до 1,42 кг/м3; и с) переработки указанного потока деасфальтизата, по меньшей мере, в ...

СПОСОБ УМЕНЬШЕНИЯ КОРРОЗИИ И ОСАЖДЕНИЯ ПРОДУКТОВ КОРРОЗИИ В БЛОКЕ ПЕРЕГОНКИ СЫРОЙ НЕФТИ

... 1. Способ оптимизации системного параметра технологического потока в блоке перегонки сырой нефти для снижения коррозии и/или осаждения продуктов коррозии в указанном блоке, согласно которому:(a) измеряют и/или прогнозируют свойство, связанное с системным параметром, в одном или более местах блока перегонки сырой нефти;(b) определяют оптимальный диапазон, связанный с измеренным и/или предсказанным свойством, при этом оптимальный диапазон может быть установлен пользователем;(c) если измеренное и/или предсказанное свойство выходит за пределы оптимального диапазона, связанного с этим свойством, вызывают изменение поступления некоторой композиции в технологический поток, при этом указанная композиция способна корректировать свойство, связанное с системным параметром таким образом, чтобы вернуть измеренное и/или предсказанное свойство в рамки указанного оптимального диапазона;(d) необязательно: (i) преобразуют измеренное свойство во входной электрический сигнал, который может быть передан на ...

ЭМУЛЬГИРОВАНИЕ УГЛЕВОДОРОДНЫХ ГАЗОЙЛЕЙ ДЛЯ ПОВЫШЕНИЯ ЭФФЕКТИВНОСТИ ПОГЛОТИТЕЛЯ СЕРОВОДОРОДА НА ВОДНОЙ ОСНОВЕ

... 1. Способ удаления сероводорода, присутствующего в тяжелой нефти, в технологическом оборудовании для углеводородных сред, включающий стадии:добавления к тяжелой нефти поглотителя на водной основе, содержащего один или более альдегидов, с использованием инжекционной системы со статическим смесителем; исоздания эмульсии поглотителя на водной основе и тяжелой нефти с использованием насоса с большим сдвиговым усилием / высокой скоростью.2. Способ по п.1, дополнительно включающий отведение части тяжелой нефти в патрубок для добавления поглотителя, добавление указанного поглотителя на водной основе к данной части тяжелой нефти и формирование эмульсии в патрубке для добавления и добавление эмульсии поглотителя на водной основе и нефти к тяжелой нефти в технологическом оборудовании.3. Способ по п.1, в котором в статическом смесителе используют диспергирующую трубку.4. Способ по п.1, в котором поглотитель на водной основе представляет собой глиоксаль.5. Способ по п.1, в котором технологическое оборудование ...

DESULPHURISATION MECHANISM AND - PROCEDURES

ENTSCHWEFELUNGSEINRICHTUNG UND -VERFAHREN

Devices and improved methods are provided for operation of ultrasonic transducers and horns.

Inhibition of corrosion in fluid systems

Inhibiting corrosion and scaling of surfaces contacted by sulfur-containing materials

A method of treatment for inhibiting sulfur-based corrosion or scaling or for removing scaling from a surface including inhibiting corrosion caused by sulfur- containing materials, reducing corrosion caused by sulfur-containing materials, inhibiting scaling caused by sulfur-containing and sulfur-containing materials in gas, liquid or solid phase or any combination of multiple phases of materials, reducing scaling caused by sulfur-containing and sulfur-containing materials, and removing scaling caused by sulfur-containing and sulfur-containing materials. The method involves contacting sulfur-containing materials with a composition containing a turpentine liquid. The method also involves contacting corrodible surfaces or surfaces prone to scaling with a composition containing a turpentine liquid.

Polymeric corrosion inhibitors

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)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)-, 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) ...

Method and apparatus for reducing fouling using resid fractions of high tan and high SBN crude oil

Atmospheric and/or vacuum resid fractions of a high solvency dispersive power (HSDP) crude oil are added to a blend of crude oil to prevent fouling of crude oil refinery equipment and to perform on-line cleaning of fouled refinery equipment. The HSDP resid fractions dissolve asphaltene precipitates and maintain suspension of inorganic particulates before coking affects heat exchange surfaces.

Method for reducing the amount of organic acids in a hydrocarbon oil fraction

Provided is a method for reducing the amount of organic acids in a hydrocarbon oil fraction by hydrogenating the organic acids in the hydrocarbon oil fraction under mild conditions. Provided is a new method able to overcome the problem of organic-acid-induced corrosion during the process of distillation, by using hydrogen or a hydrogen-containing mixed gas and a hydrogenation catalyst to subject the organic acids in the hydrocarbon oil fraction to hydrogenation at an appropriate temperature and pressure, thereby converting the same to hydrocarbons and so reducing the amount of organic acids in the hydrocarbon oil fraction.

Process for converting a solid biomass material

A process for converting a solid biomass material, comprising contacting the solid biomass material with a catalytic cracking catalyst at a temperature of more than 400°C in a riser reactor to produce one or more cracked products, wherein the riser reactor is an internal riser reactor.

METHOD OF DISPERSING HYDROCARBON FOULANTS IN HYDROCARBON PROCESSING FLUIDS

PROCESS AND INSTALLATION INCLUDING SOLVENT DEASPHALTING AND EBULLATED-BED PROCESSING

This invention relates to a novel method for economically processing vacuum residue from heavy crude oils by selectively processing the difficult and easy components in reactors whose design and operating conditions are optimized for the specific feed. The process utilizes an integrated solvent deasphalting (SDA)/ebullated-bed design wherein the heavy vacuum residue feedstock is initially sent to an SDA unit operated with C4/C5 solvent to achieve a high deasphalted oil (DAO) yield. The resulting SDA products, namely asphaltenes and DAO are separately treated in ebullated-bed reactor(s) systems whose design and operating conditions are optimized for a particular feedstock. The resulting net conversion, associated distillate yield and product qualities are greatly improved relative to treatment of the entire residue feedstock in a common ebullated~bed reactor, system.

INHIBITION OF CORROSION IN FLUID SYSTEMS

METHOD OF REDUCING CORROSION IN A CRUDE UNIT

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.

METHOD AND APPARATUS FOR REDUCING FOULING USING RESID FRACTIONS OF HIGH TAN AND HIGH SBN CRUDE OIL

Atmospheric and/or vacuum resid fractions of a high solvency dispersive power (HSDP) crude oil are added to a blend of crude oil to prevent fouling of crude oil refinery equipment and to perform on-line cleaning of fouled refinery equipment. The HSDP resid fractions dissolve asphaltene precipitates and maintain suspension of inorganic particulates before coking affects heat exchange surfaces.

AN EFFECTIVE NOVEL POLYMERIC ADDITIVE FOR INHIBITING NAPTHENIC ACID CORROSION AND METHOD OF USING THE SAME

The present invention relates to the field of inhibition of metal corrosion in hot acidic hydrocarbons, wherein acidity is derived from presence of naphthenic acid. More particularly, it relates to a polymeric additive for inhibiting high temperature napthenic acid corrosion, wherein said polymeric additive is polymeric phosphate ester of polyisobutylene succinate ester or oxide derivative of polymeric phosphate ester of polyisobutylene succinate ester. A polymeric phosphate ester of polyisobutylene succinate ester which is capable of acting as naphthenic acid corrosion inhibitor by inhibiting naphthenic acid corrosion in crude oil/feedstock/hydrocarbon streams containing naphthenic acid, and demonstrating higher thermal stability at elevated temperature varying from about 200°C to about 400°C [about 400°F to about 750°F] is disclosed ...

METHODS OF ISOLATING AND USING COMPONENTS FROM A HIGH SOLVENCY DISPERSIVE POWER (HSDP) CRUDE OIL

Method of isolating active resins from a high solvency dispersive power (HSDP) crude oil includes providing a HSDP crude oil, deasphalting the HSDP crude oil into at least a deasphalted oil (DAO) fraction and a first asphaltenes fraction, deasphalting the first asphaltenes fraction to isolate active resins from a second asphaltenes fraction, and combining the DAO fraction and the second asphaltenes fraction to form a de-resinated crude. Method of using components isolated from a high solvency dispersive power (HSDP) crude oil includes providing a HSDP crude oil, deasphalting the HSDP crude oil into at least a deasphalted oil (DAO) fraction and a first asphaltenes fraction, deasphalting the first asphaltenes fraction to isolate active resins from a second asphaltenes fraction, and selecting at least one of the DAO fraction, the active resins, or the second asphaltenes fraction for use in a refinery process.

METHODS AND SYSTEMS FOR PROCESSING A REACTION PRODUCT MIXTURE OF A CELLULOSIC BIOMASS MATERIAL

Processing of a reaction product mixture containing at least one volatile organic compound as well as lignin, lignin derived compounds, and/or unextracted cellulose and hemicellulose using a recovery system comprising at least two flashers or at least one flasher and at least two reboilers. In a particular embodiment, the reaction product mixture comes from reactions involving deconstruction (or digestion) of biomass, particularly cellulosic biomass which contains various polysaccharides (e.g., carbohydrates) and lignin.

METHOD AND COMPOSITION FOR PREVENTING CORROSION OF METAL SURFACES

The present invention provides a corrosion inhibitor composition comprising: a carrier; at least one compound of formulae (ll)-(VII) or a salt or quaternised derivative thereof: wherein R is C5-21 alkyl or alkenyl, preferably alkyl; each R1 is independently an optionaliy substituted group of formula -(CH2)nX wherein n is an integer from 1 to 6 and X is C(O)OZ or SO3Z and Z is H or a cation; and R' is C4-20 alkyl or alkenyl, preferably alkyl; and a quaternary ammonium compound.

HEAT RECOVERY FOR BITUMEN FROTH TREATMENT PLANT INTEGRATION WITH TEMPERATURE CIRCULATION LOOP CIRCUITS

A system for recovering heat from a bitumen froth treatment plant use temperature circulation loop circuits. The system has high temperature and low temperature cooling exchangers associated with the plant; the circulation loop circuits; and an oil sands process fluid line. The circuits include a high temperature circulation loop for circulating heat exchange media for recovering heat from the high temperature cooling exchangers to produce a heated media, and a low temperature circulation loop for circulating a cooling media for recovering heat from the low temperature cooling exchangers and producing a heated cooling media. The oil sands process fluid line is in heat exchange connection with the high temperature circulation loop and the low temperature circulation loop, such that the heated media and the heated cooling media transfer heat to the oil sands process fluid to produce a heated process fluid.

slozhnopoliefirnyepoliaminnye and slozhnopoliefirnyepolichetvertichnye ammonium corrosion inhibitors

КОМПОЗИТНЫЙ МАТЕРИАЛ

Композитный материал, предназначенный для компонентов, используемых в коррозионных условиях окружающей среды, в котором названный материал включает коррозионно-устойчивую часть (1) и несущую нагрузку часть (2), в котором названные части (1, 2) располагаются примыкающими друг к другу, в котором коррозионно-устойчивая часть представляет собой медно-алюминиевый сплав (Cu/Al) и в котором несущая нагрузку часть включает сплав на основе железа (Fe), никеля (Ni) или кобальта (Со). Изобретение характеризуется тем, что диффузионный барьер (3) располагается между коррозионно-устойчивой частью (1) и несущей нагрузку частью (2) и что диффузионный барьер (3) содержит одним из компонентов хром (Cr) или железо (Fe) или железо (Fe), которое содержит в качестве легирующего вещества хром (Cr) или углерод (С).

ЭКСТРАКЦИЯ УГЛЕВОДОРОДОВ ИЗ УГЛЕВОДОРОДСОДЕРЖАЩИХ МАТЕРИАЛОВ И/ИЛИ ПЕРЕРАБОТКА УГЛЕВОДОРОДСОДЕРЖАЩИХ МАТЕРИАЛОВ

В заявке описан способ экстракции углеводородсодержащего органического материала из углеводородсодержащего материала, который включает следующие стадии: получение первой жидкости, включающей терпентиновую жидкость, контактирование углеводородсодержащего материала с терпентиновой жидкостью, при этом получают экстракционную смесь, экстракция углеводородного материала в терпентиновую жидкость и отделение экстрагированного углеводородного материала от не экстрагированного остаточного материала.

СПОСОБ УМЕНЬШЕНИЯ КОРРОЗИИ В СИСТЕМЕ ОБРАБОТКИ ОТХОДЯЩЕГО ПОТОКА ПРОЦЕССА ПРЕВРАЩЕНИЯ МЕТАНОЛА В ОЛЕФИНЫ

Предложен способ уменьшения коррозии в системе обработки отходящего из процесса метанол-в-олефины (МвО) потока, в частности в системе удаления из него конденсата, посредством инжекции нейтрализующего агента на одном или нескольких целевых участках системы обработки отходящего из МвО потока. Нейтрализующий агент гарантирует, что любая локальная конденсация в системе обработки отходящего из МвО потока, в частности в системе удаления конденсата, происходит в основных условиях и что нейтрализуются все кислые способные конденсироваться компоненты. Описан также мониторинг коррозии в системе обработки отходящего из МвО потока и мониторинг рН участков локальной коррозии для гарантии надлежащей нейтрализации любого образовавшегося на них кислого конденсата.

APPLICATION SLOZhNOPOLIEFIRPOLIAMINNYKhSLOZhNOPOLIEFIRPOLIAMMONIINYKh AND QUATERNARY COMPOUNDS AS CORROSION INHIBITORS

REDUCTION TO MINIMUM CORROSION IN PROCESSING SYSTEM OF EFFLUENT FLOW PROCESS CONVERSION OF METHANOL INTO OLEFINS

CLEANING OF PLANTS HF-ALKYLATION OF

USE OF POLYESTER POLYAMINE AND POLYESTER POLYQUATERNARY AMMONIUM COMPOUNDS AS CORROSION INHIBITORS

КОМПОЗИТНЫЙ МАТЕРИАЛ

Композитный материал, предназначенный для компонентов, используемых в коррозионных условиях окружающей среды, в котором названный материал включает коррозионно-устойчивую часть (1) и несущую нагрузку часть (2), в котором названные части (1, 2) располагаются примыкающими друг к другу, в котором коррозионно-устойчивая часть представляет собой медно-алюминиевый сплав (Cu/Al) и в котором несущая нагрузку часть включает сплав на основе железа (Fe), никеля (Ni) или кобальта (Со). Изобретение характеризуется тем, что диффузионный барьер (3) располагается между коррозионно-устойчивой частью (1) и несущей нагрузку частью (2) и что диффузионный барьер (3) содержит одним из компонентов хром (Cr) или железо (Fe) или железо (Fe), которое содержит в качестве легирующего вещества хром (Cr) или углерод (С).

Ethylene furnace process and system

HEAT RESISTANT ALLOY FOR CARBURIZATION RESISTANCE

An Effective Novel Polymeric Additive for Inhibiting Napthenic Acid Corrosion and Method of Using the Same

ADDITIVES FOR REDUCING COKING OF FURNACE TUBES

Fouling of hot furnace surfaces in selected refinery processes can be stopped or at least mitigated using an antifouling agent. The antifouling agents include sulfurized oil and may include other components selected from the group consisting of magnesium and aluminum overbases, α-olefin copolymers, and combinations thereof. It is emphasized that this abstract is provided to comply with the rules requiring an abstract which will allow a searcher or other reader to quickly ascertain the subject matter of the technical disclosure. It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims.

METHOD FOR REDUCING FOULING IN FURNACES

Heat exchanger fouling in organic chemical production processes may be reduced using an antifoulant additive. The antifoulant additive may have one component selected from the group consisting of an alkylphosphate ester, and an alpha olefin maleic anhydride copolymer; or it may have two components selected from the group consisting of a metallic overbase, an alkylphosphate ester, and an alpha olefin maleic anhydride copolymer, wherein at least one of the two components in not an overbase. An additive having three components: a metallic overbase, an alkylphosphate ester, and an alpha olefin maleic anhydride copolymer; is also within the scope of the disclosure. The abstract is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims.

METALLIC COMPOSITE COMPRISING A LOAD-BEARING MEMBER AND A CORROSION RESISTANT LAGER

A composite material intended for components used in corrosive environments, wherein said material comprises a corrosion-resistant part (1) and a load-bearing part (2), wherein said parts (1, 2) 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 (3) is disposed between the corrosion-resistant part (1) and the load-bearing part (2), and in that the diffusion barrier (3) 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).

PETROLEUM BIOPROCESSING TO PREVENT REFINERY CORROSION

The present invention relates to the bioupgrading of crude oil is directed to a process for decreasing the acidity of an acidic crude oil, comprising contacting an acidic crude oil with a mixture nitrogen containing compounds selected from the group comprising ammonia, ammonia hydroxide, amines and the salts thereof, and in the presence of lipase enzyme, under conditions of suitable temperature and pressure sufficient to form the corresponding amide. The resulting naphthenic acid derived amides can then be processed normally in a refinery using such processes as cracking or hydrotreating and converted to hydrocarbon, ammonia and carbon dioxide without causing damage to the refinery infrastructure. This enzyme process is done at reduced temperatures (40-60° C.) and pressures requiring less energy.

Method to decrease decomposition products in solutions that absorb acidic gases such as carbon dioxide and the like in the presence of oxygen

An amine solvent solution that is useful in absorbing acid gases from a liquid or gas feed stream may have an amine additive added thereto. Additionally or alternatively, the amine additive may be added to a liquid or gas feed stream. The addition of the amine additive decreases the presence of amine-derived contaminants and/or degradation of amine in the amine solvent solution. As such, the amine solvent solution is available for effective reuse in treating the liquid or gas feed stream and there may be a decrease in the corrosion within an amine treating system.

Method for preventing corrosion of metals in steam generating units, petroleum and crude oil atmospheric distillation units

A NEW ADDITIVE FOR INHIBITING ACID CORROSION AND METHOD OF USING THE NEW ADDITIVE

СПОСОБ, УСТРОЙСТВО И ХИМИЧЕСКИЕ ПРОДУКТЫ ДЛЯ ОБРАБОТКИ НЕФТЯНОГО ОБОРУДОВАНИЯ

FIELD: chemistry. SUBSTANCE: in the invention, a device and methods for processing an oil refinery device or oil refinery device equipment during operation of the said oil refinery device are proposed, wherein in particular the method includes support during the processing period, the oil refinery device in the operation mode common to the plant itself, which includes supplying fresh feedstock to the oil refinery device; while maintaining the oil refinery device in the operation mode, one or both of the actions selected from a) and b) are performed; a) introducing into the oil refinery device, during the processing period, a processing hydrocarbon-based fluid; b) changing the set feed rate used at the beginning of the processing of the oil refinery device or the oil refinery device equipment. The set feed rate is changed ranging from the maximum operating speed for the oil refinery device, including the design speed for the oil refinery device, to the minimum operating speed, which is set at the level corresponding to the operating state of the oil refinery device with minimal performance; where the specified hydrocarbon-based processing fluid is selected from the group consisting of the products of crude oil distillation received for the oil refinery device and/or in any case present in the oil refinery device for final processing of the products, mixing of end products, intermediates or raw materials in the oil refinery device. The said introduction of a hydrocarbon-based processing fluid and/or the said change in the feed rate during processing creates an additional source or sources for distillation with respect to the amount obtained at a predetermined rate; and distilling the said additional source or sources for distillation in order to process the device. EFFECT: said processing can be attributed to the cleaning of the equipment to improve output compared to normal working conditions and to reduce coke-formation and removal of coke from catalysts. 53 cl, 10 ...

ИНГИБИТОР ВЫСОКОТЕМПЕРАТУРНОЙ КОРРОЗИИ

... 1. Способ ингибирования коррозии внутренних металлических поверхностей оборудования, используемого при переработке сырой нефти или высокотемпературных дистиллятов, нагреваемых до температур между примерно 350°F и примерно 790°F, включающий добавление к сырой нефти или высокотемпературному нефтяному дистилляту ингибирующего коррозию количества ингибитора коррозии, выбранного из группы из (I) и (II) и их смесей, где указанный ингибитор коррозии (I) имеет формулув которой W, X, Y и Z присутствуют все и могут быть одинаковыми или различными и выбираются индивидуально из группы, состоящей из (OH), (COOH) и COOR, при условии, что смежные пары W, X, Y и Z могут быть выбраны изRпредставляет алкильную группу, имеющую от примерно 1 до примерно 16 атомов углерода; и Ar представляет ароматическое соединение; иуказанный ингибитор коррозии (II) имеет формулув которой Rи Rпредставляют COOR,при условии, что, когда один из Rили Rпредставляетто другой представляет илидостаточные для образования ангидридной ...

VERFAHREN ZUR BILDUNG EINER SCHUTZSCHICHT AUS MANGAN- UND CHROMOXYD

USE FROM MANGANESE CONNECTIONS TO THE SUPPRESSION OF THE NIEDERUND HIGH-TEMPERATURE CORROSION IN INDUSTRIAL FURNACES

KORROSIONSMINIMISIERUNG IN A MTO VERFAHRENABWASSERBEHANDLUNGSSYSTEM ONE

Method of blending high tan and high SBN crude oils and method of reducing particulate induced whole crude oil fouling and asphaltene induced whole crude oil fouling

A new additive for inhibiting acid corrosion and method of using the new additive

The present invention relates to the field of corrosion inhibition in hydrocarbon fluid processing units. The present invention comprises a new additive for inhibiting acid corrosion comprising polymeric thiophosphate ester, which is obtained by reaction of a polymer compound having mono, di or poly hydroxyl group, preferably polymer compound which is hydroxyl - termination, more preferably said polymer compound comprising hydroxyl - terminated polyisobutylene or polybutene and phosphorous pentasulphide. Said polymeric thiophosphate ester is further reacted with any oxide selected from group consisting of ethylene oxide, butylenes oxide or propylene oxide or such other oxide, preferably ethylene oxide, capably forming ethylene oxide derivative of thiophosphate ester. The invention is useful effecting acid corrosion inhibition on the metal surfaces of a distillation unit, distillation column, trays, packing and pump around piping.

Method for reducing the amount of organic acids in a hydrocarbon oil fraction

Provided is a method for reducing the amount of organic acids in a hydrocarbon oil fraction by hydrogenating the organic acids in the hydrocarbon oil fraction under mild conditions. Provided is a new method able to overcome the problem of organic-acid-induced corrosion during the process of distillation, by using hydrogen or a hydrogen-containing mixed gas and a hydrogenation catalyst to subject the organic acids in the hydrocarbon oil fraction to hydrogenation at an appropriate temperature and pressure, thereby converting the same to hydrocarbons and so reducing the amount of organic acids in the hydrocarbon oil fraction.

Process for reforming hydrocarbons

The invention relates to a process for the production of synthesis gas by the use of autothermal reforming in which tail gas from downstream Fischer-Tropsh synthesis is hydrogenated and then added to the autothermal reforming stage.

HIGH-TEMPERATURE TREATMENT OF HYDROCARBON-CONTAINING MATERIALS

In the treatment of a hydrocarbon-containing material at temperatures of 500.degree.C or above in an apparatus made of a nickel-containing heat-resistant steel, the surfaces of the apparatus that are exposed to the hydrocarbon-containing material are coated with a member selected from nickel-free metals, nickel-free alloys, nickel-free oxides or nitrides, and silicon carbides, whereby the deposition of carbon on those surface is prevented.

HEAT RESISTANT ALLOY FOR CARBURIZATION RESISTANCE

METHOD FOR REDUCING CORROSIVE IONS IN AROMATIC COMPOUND EXTRACTION SOLVENT

Provided is a method for reducing corrosive ions in an aromatic compound extraction solvent, which easily and efficiently reduces corrosive ions in an aromatic compound extraction solvent in a circulatory system for the purpose of suppressing corrosion of an extraction device caused by corrosive ions contained in the aromatic compound extraction solvent. A method for reducing corrosive ions in an aromatic compound extraction solvent in a circulatory system in which the aromatic compound extraction solvent is circulated. This method for reducing corrosive ions in an aromatic compound extraction solvent comprises: a step wherein a corrosive ion scavenger is added to the corrosive ions, which are at least one kind of ions selected from among chloride ions, sulfate ions and sulfite ions, thereby having the corrosive ions react with the corrosive ion scavenger so as to obtain a non-volatile salt; and a step wherein the salt is removed by concentrating the solvent that contains the salt.

Polymeric corrosion inhibitors

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.

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

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).

Anti-coking process and equipment for oiling waste rubber or waste plastic, and coking remover

An anti-coking process is provided for oiling the rubber or plastic waste, and it involves the pyrolysis process that comes with the emission of hot air to be mixed with the high-temperature hot air that is ready to be sent into pyrolysis device. The equipment described includes a return air pipeline being connected to the hot air outlet. Meanwhile, a coking cleaning device is also introduced to remove the coke residual on the pyrolysis device wall in the cracking process. This device consists of a scraper, which, through the role of weights, is able to work with the inside surface of the cracking device.

Enclosure of an FCC Unit Comprising an Inner Support Device Rigidly Connected to Cyclones

The invention relates to an enclosure () of a fluid catalytic cracking unit in which an inner space is defined by a side wall () having a longitudinal axis extending substantially in the direction of gravity, said enclosure being provided with a plurality of mechanical separation cyclones () located inside the inner space. The enclosure () comprises a supporting device () attached only to the cyclones () by: an annular peripheral support element () extending along the side wall () in a plane perpendicular to the longitudinal axis (X), separated from the side wall by a predetermined clearance; and a plurality of beams () extending in the same plane as the peripheral support element (), the beams being rigidly connected to the peripheral support element and to at least one mechanical separation cyclone by one end or by an attachment part distant from the ends thereof. 116.-. (canceled)17. A chamber of a fluid catalytic cracking unit comprising a lateral wall which delimits an internal volume having a longitudinal axis extending substantially in the direction of gravity , said chamber being provided with a plurality of mechanical separation cyclones situated inside said internal volume , characterized in that said chamber comprises , inside said internal volume , a support device secured only to the mechanical separation cyclones and comprising:a peripheral support element extending along the lateral wall in a plane perpendicular to the longitudinal axis (X), distant from the lateral wall by a predetermined clearance in the plane of the support element,a plurality of beams extending in the same plane as the peripheral support element, the beams being secured to the peripheral support element and to at least one mechanical separation cyclone by an end or by a fixing part distant from its ends.18. The chamber as claimed in claim 17 , characterized in that the support device comprises other beams extending in the same plane as the peripheral support element and chosen ...

PROCESS FOR REFORMING HYDROCARBONS

A process for the production of synthesis gas by the use of autothermal reforming in which tail gas from downstream Fischer-Tropsh synthesis is hydrogenated and then added to the autothermal reforming stage. 1. Process for the production of liquid hydrocarbons from a hydrocarbon feedstock comprising:a) passing said hydrocarbon feedstock through an ATR, CPO or POx, and withdrawing a stream of hot effluent synthesis gas from the ATR, CPO or PDX,b) converting the synthesis gas into liquid hydrocarbons via Fischer-Tropsch synthesis,{'b': '1', 'c) passing tail gas from the Fischer-Tropsch synthesis stage through a hydrogenation stage to produce a hydrogenated tail gas containing less than mol olefins, and'}d) adding the hydrogenated tail gas directly to said ATR, CPO or Pox;e) optionally recovering the liquid hydrocarbons produced.2. Process according to claim 1 , wherein said hydrocarbon feedstock is a gas that has passed through at least one adiabatic pre-reforming stage.3. Process according to claim 1 , wherein said hydrocarbon feedstock is a gas that has passed through at least one steam reforming stage.4. Process according to claim 1 , wherein said hydrocarbon feedstock is a gas mixture resulting from dividing a raw hydrocarbon feed gas into two streams claim 1 , passing the first stream through at least one steam reforming stage to form a primary reformed gas claim 1 , using the second stream as a by-pass stream to said steam reforming stage claim 1 , and subsequently combining said primary reformed gas with the by-pass stream to form said hydrocarbon feedstock.5. Process according to claim 1 , comprising dividing a raw hydrocarbon feed gas into two streams claim 1 , by which one of the streams becomes said hydrocarbon feedstock claim 1 , and passing the other stream through at least one steam reforming stage to form a reformed gas.6. Process according to claim 3 , wherein the steam reforming stage is heat exchange reforming claim 3 , and where at least a portion ...

COMPOUNDS AND METHODS FOR INHIBITING CORROSION IN HYDROCARBON PROCESSING UNITS

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 ...

FOULING MITIGATION IN ALKANOLAMINE TREATING SYSTEMS

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 ...

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

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 ...

SERPENTINE FLUID REACTOR COMPONENTS

Some embodiments of the present invention provide components for a serpentine fluid reactor which is optimized for one or more objective functions of interest such as pressure drop, erosion rate, fouling, coke deposition and operating costs. The components are designed by computer modeling the components individually and collectively in which the cross section of flow path is substantially circular under industrial conditions to validate the model design and its operation. Then iteratively the component designs are deformed and the operation of the deformed part(s) is modeled and compared to values obtained with other deformed models until the value of the objective function is optimized (e.g. at an extreme) or the change in the objective function is approaching zero. 2. The method according to claim 1 , wherein the first pipe sections are part of a high pressure olefin polymerization reactor wherein the hydrocarbon comprises ethane.3. The method according to claim 1 , wherein the first pipe section is part of the furnace tubes of an olefin cracker.4. The method according to claim 3 , wherein over 90% of the flow passage does not change by more than 7% over an about 5% length of the flow path.5. The method according to claim 4 , wherein the ARQ at one or more sections over said 90% of the length of the flow passage is from about 1.02 and about 1.12.6. The method according to claim 5 , wherein the ARQ over said 80% of the length of the flow passage does not change by more than about 5% over an about 5% length of the flow path.722-. (canceled)23. The method according to claim 6 , wherein the ARQ at one or more sections over said remaining about 80% of the length of the flow passage is from about 1.02 and about 1.15.24. The method according to claim 23 , wherein the serpentine reactor has an increasing cross sectional area in the direction of flow such that the angle between the transverse normal vector and the pipe walls range from about 0° to about 85°.25. The method ...

MOLECULAR ENHANCED BASED SURFACE ENHANCED RAMAN SPECTROSCOPY TO DETECT LOW CONCENTRATION OF MONOETHANOLAMINE

A system and method for estimating a concentration of monoethanolamine (MEA) in a fluid. A substrate for supporting a sample of the fluid during testing includes a carbon nanotube mat layer, a silver nanowire layer disposed on the carbon nanotube mat layer, and a chemical enhancer layer disposed on the silver nanowire layer. A sample of the fluid is placed on the substrate, and the fluid sample is radiated with electromagnetic radiation at a selected energy level. A detector measures a Raman spectrum emitted from the sample in response to the electromagnetic radiation. A processor estimates the concentration of MEA in the sample from the Raman spectrum and adds a corrosion inhibitor to the fluid in an amount based on the estimated concentration of MEA to reduce the concentration of MEA in the fluid. 1. A method of estimating a concentration of monoethanolamine (MEA) in a fluid , comprising: a carbon nanotube mat layer,', 'a silver nanowire layer disposed on the carbon nanotube mat layer, and', 'a chemical enhancer layer disposed on the silver nanowire layer, wherein the fluid sample is placed on the chemical enhancer layer;, 'placing a sample of the fluid on a substrate includingradiating the fluid sample with electromagnetic radiation at a selected energy level;measuring a Raman spectrum emitted from the fluid sample in response to the electromagnetic radiation;estimating the concentration of MEA in the sample fluid from the Raman spectrum; andadding a corrosion inhibitor to the fluid in an amount based on the estimated concentration of MEA to reduce the concentration of MEA.2. The method of claim 1 , wherein the chemical enhancer layer includes a chemical having a thiol group for bonding to the silver nanowire layer and at least one of a carboxyl group and a boronyl group for bonding to the MEA.3. The method of claim 1 , wherein the chemical enhancer layer includes at least one of:4-mercaptobenzoic acid (4-MBA), 2-mercaptopyridine, 4-bromothiophenol, and 4- ...

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

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.

IONIC LIQUIDS AND METHODS OF USING SAME

Ionic liquid containing compositions may be used in the production, recovery and refining of oil and gas. In addition, they may be used to treat wastewater and/or to inhibit and/or prevent fouling of contaminants onto surfaces. 1. (canceled)2. (canceled)3. (canceled)4. (canceled)5. (canceled)6. (canceled)7. (canceled)8. (canceled)9. (canceled)10. (canceled)11. (canceled)12. (canceled)13. (canceled)14. (canceled)15. (canceled)16. (canceled)17. (canceled)18. (canceled)19. (canceled)20. (canceled)21. (canceled)22. (canceled)23. (canceled)24. (canceled)25. (canceled)26. (canceled)27. (canceled)28. (canceled)29. (canceled)30. (canceled)33. The method of claim 32 , wherein R claim 32 , R claim 32 , R claim 32 , R claim 32 , R claim 32 , Rand Rare independently —H or a Calkyl and/or the anion is a halide selected from the group consisting of —Cl claim 32 , —Br claim 32 , —F or —I.35. A method of treating a hydrocarbon containing fluid to:(a) inhibit or prevent the formation or precipitation of asphaltenes in the fluid; or [{'br': None, 'sup': 1', '2', '3', '4', '+', '−, 'RRRRNX\u2003\u2003(IV); or'}, {'br': None, 'sup': 1', '2', '3', '+', '8', '+', '5', '6', '7', '−, 'RRRNRNRRRX\u2003\u2003(V)'}], '(b) remove or reduce sulfur containing compounds in the fluid, the method comprising contacting the fluid with an ionic liquid of the formula{'sup': 1', '2', '3', '4', '5', '6', '7', '8, 'X is an anion selected from the group consisting of halides; hydroxyl; carbonates; alkyl carbonates; bicarbonates; carboxylates; hydroxycarboxylates; sulfonates; sulfates; bisulfites; thiocyanates; dithiocarbonates; dithiocarbonates; trithiocarbonates; carbamates; dithiocarbamates; trithiocarbamates; xanthates; sulfides; polysulfides; alkoxides; anionic ureas; anionic alkyl substituted phosphines; anionic amino fatty acids; anionic alkoxylated fatty acids; anionic acrylamido-methyl propane sulfonate/acrylic acid copolymers; anionic phosphated maleic copolymers; anionic metal complexes; sulfur ...

Partial Trip System for Ethylene Furnace with Ground Flare

Systems and methods are provided for performing a partial trip for an ethane steam cracker while reducing or minimizing ethane consumption in a ground flare system during the partial trip. In particular, a trip system is provided that reduces the firing on an ethylene furnace (such as a reduction into a range of 10% to 40% of normal firing) while also providing a reduced flow of feed to the furnace with dilution steam at a steam to hydrocarbon ratio similar to a ratio that is suitable during normal operation. The trip system can be actuated, for example, when the loss of circulating quench water to the water quench tower is detected. 1. A method for operating a steam cracker , comprising:combusting fuel comprising a first fuel heating value in one or more burners of a steam cracker furnace, the furnace comprising a plurality of process tubes;passing a first feed comprising ethane and steam to the plurality of process tubes at a process tube inlet temperature of about 840° C. or more to form a product comprising ethylene, a volume ratio of steam to hydrocarbon in the feed being about 0.2 to about 0.5;separating an ethylene-containing stream from the product comprising ethylene in a water quench system;detecting a condition indicating a stop in operation of a component downstream from the water quench system;combusting, based on the detected condition, fuel comprising a second fuel heating value in the one or more burners, the second fuel heating value being 10% to 40% of the first fuel heating value;passing, based on the detected condition, a second feed comprising ethane and steam into the plurality of process tubes at a process tube inlet temperature of about 538° C. or more to produce an exit stream comprising ethane and steam, a volume ratio of steam to hydrocarbon in the second feed being about 0.2 to about 0.5, a ratio of a volume flow rate of the second feed relative to a volume flow rate of the first feed being about 0.3 to about 0.6; anddirecting at least a ...

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

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.

UPFLOW REACTOR

An upflow reactor (), comprising a housing (), a catalyst bed layer () and a pressing device (). The housing () is internally provided with a reaction chamber (), a reaction material inlet () and a reaction material outlet () which are in communication with the reaction chamber () are provided on the housing (); the catalyst bed layer () is provided within the reaction chamber (), the pressing device () is provided within the reaction chamber () and located above the catalyst bed layer (), and at least a part of the pressing device () is provided to be movable up and down, so that the at least a part of the pressing device () can be pressed against the catalyst bed layer (). 1. An upflow reactor , comprising:a housing provided with a reaction chamber therein, and provided with a reaction material inlet and a reaction material outlet thereon, which are in communication with the reaction chamber;a catalyst bed layer arranged in the reaction chamber; anda pressing device arranged in the reaction chamber and located above the catalyst bed layer, wherein at least a part of the pressing device is arranged to be movable up and down, so that the at least a part of the pressing device is able to be pressed against the catalyst bed layer.2. The upflow reactor of claim 1 , wherein the upflow reactor comprises a plurality of catalyst bed layers and a plurality of pressing devices claim 1 , the plurality of catalyst bed layers and the plurality of pressing devices are disposed alternately in the vertical direction claim 1 , and each of the pressing devices is able to be pressed against one of the catalyst bed layers; optionally claim 1 , the plurality of catalyst bed layers are in height incremented in the material feeding direction.3. The upflow reactor of claim 1 , wherein the catalyst bed layer comprises an upper catalyst section and a lower catalyst section claim 1 , wherein the upper catalyst section is positioned above the lower catalyst section claim 1 , and the pressing ...

Refinery Antifoulant Process

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.

Decoking Process

In chemical processes for cracking hydrocarbons, reactors are subject to coking. This results in carburization of the metal substrate for the reactor leading to a reduced reactor life. If the reactor is subject to a decoke process, followed by a steam scour and nitrogenating there is a reduced tendency to carburization of the metal substrate improving the reactor life. 1. A process for decoking of a reactor for the conversion of a chemicals feedstock at a temperature greater than 700° C. , the decoking giving a scoured reactor surface which contacts hydrocarbons and further comprising treating the scoured reactor surface with a mixture comprising steam and nitrogen in a weight ratio from 20:1 to 30:1 in an amount from 80 to 110 kg/hour per reactor at a temperature from 750° C. to 850° C. for a time not less than 20 minutes , in the absence of added oxygen.2. The process according to claim 1 , wherein the reactor comprises stainless steel selected from the group consisting of wrought stainless steel claim 1 , austenitic stainless steel HP stainless steel claim 1 , HT stainless steel claim 1 , HU stainless steel claim 1 , HK stainless steel claim 1 , HW stainless steel claim 1 , HX stainless steel claim 1 , heat resistant steel claim 1 , and nickel based alloys.3. The process according to claim 2 , wherein the decoking giving the scoured reactor surface scouring comprises comprising treating a reactor surface which contacts hydrocarbons with a steam scour at a rate of not less than 2500 kg/hour/reactor for a time from 0.5 to 10 hours.4. The process according to claim 3 , wherein the decoking comprises subjecting the reactor prior to the scouring to a decoking air burn for a period of time sufficient so that air leaving the reactor has a total carbon oxide content less than 2 claim 3 ,000 ppm.5. The process according to claim 1 , wherein subsequent the treating with nitrogen and steam claim 1 , the reactor is treated with a chemical to reduce coking selected from the ...

Methods of using ionic liquids as corrosion inhibitors

Ionic liquid containing compositions may be used in the production, recovery and refining of oil and gas. In addition, they may be used to treat cooling water and/or to inhibit and/or prevent corrosion of metals.

MECHANICALLY RESILIENT BITUMEN MICROCAPSULES FOR MIDSTREAM TRANSPORT

Disclosed herein are methods of preparing bitumen for transport, apparatus for preparing bitumen for transport, methods of transporting bitumen, and transportation-ready forms of bitumen. Instead of relying on exogenous components to induce bitumen solidification, the methods and apparatus of the present disclosure reorganize bituminous materials derived from the same origin into core-shell bitumen microcapsules, such that relatively low solubility components (e.g. asphaltenes) encapsulate relatively high solubility components (e.g. maltenes). Importantly, the bitumen microcapsules of the present disclosure are sufficiently mechanically resilient to meet one or more thresholds for midstream transportation, and they are readily fluidized for downstream processing with conventional technologies. Taken together, these aspects may ameliorate one or more challenges in achieving commercially viable bitumen solidification technologies.

METHOD OF TREATING A HYDROCARBON STREAM

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 ...

Radiofrequency Pump Inlet Electric Heater

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 ...

THERMAL DECOMPOSITION IN CHEMICAL LOOPING COMBUSTION

A method is presented of thermal decomposition to crack ethane and/or higher alkane hydrocarbon feed or the mixture of any of these hydrocarbons to break down into component elements or simpler constituents using heat from a hot metal agent from a chemical looping combustion process. 1. A process for thermally cracking one or more C-Chydrocarbons comprising integrating a chemical looping combustion reaction with a steam cracker comprising:{'sup': −1', '−1, 'passing a moving bed of reduced inorganic particulates having a melting temperature greater than 1500° C. and a particle size from 10 to 300 microns through an oxidation reactor at a temperature from 300° C. to 1200° C. for a period of time less than 2 minutes at a gas hourly space velocity for an oxidant from 500 hrto 6000 hr, and a weight hourly space velocity from 0.5 to 60, wherein not less than 20 wt % of said reduced inorganic particulates passing through said oxidation reactor are oxidized to produce oxidized inorganic particulates;'}{'sup': −1', '−1, 'passing said oxidized inorganic particulates to and through a moving bed in a fuel reactor together with a fuel in the absence of a gaseous oxidant for a period of time of less than 2 minutes at a gas hourly space velocity for the fuel from 500 hrto 6000 hr, and a weight hourly space velocity from 0.5 to 60, to substantially burn the fuel and any surface carbon on the oxidized inorganic particulates and reduce the oxidized inorganic particulates and heat them to a temperature from 1000° C. to 1200° C. to produce heated reduced inorganic particulates;'}{'sup': −1', '−1, 'sub': '2', 'passing said heated reduced inorganic particulates as a moving bed through at least a portion of a dehydrogenation reactor, concurrently or counter-currently, optionally with steam and one or more alkanes at a temperature from 750° C. to 1200° C. for a period of time less than 2 minutes at a gas hourly space velocity for the one or more alkanes from 500 hrto 6000 hr, and a weight ...

ETHYLENE FURNACE PROCESS AND SYSTEM

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 ...

PROCESS FOR CONTROLLING CORROSION IN PETROLEUM REFINING UNITS

A process for controlling corrosion and fouling in petroleum refining units. The corrosion controlling agent comprises an amine and an alcohol. The process comprises the step of adding the amine and the alcohol to the overhead system of the petroleum refining unit, either separately or in combination. 1. A process for controlling corrosion in an overhead system of a refining unit comprising water condensate and petroleum products comprising the step of adding to the system an amine and an alcohol.2. The process of wherein the amine is an alkylamine claim 1 , an alkanolamine claim 1 , or mixtures thereof.3. The process of wherein the amine is dimethylethanolamine (DMEA) claim 1 , dimethylisopropanolamine (DMIPA) claim 1 , ethylenediamine (EDA) claim 1 , methoxypropylamine (MOPA) claim 1 , monoethanolamine (MEA) claim 1 , dimethylaminopropylamine (DMAPA) claim 1 , morpholine claim 1 , trimethylamine (TMA) claim 1 , picoline claim 1 , pyridine claim 1 , or mixtures thereof.4. The process of wherein the alcohol is a polyol claim 1 , polyether diol claim 1 , polyether triol claim 1 , or mixtures thereof.5. The process of wherein the alcohol is a polyol based on ethylene glycol reacted with ethylene oxide claim 1 , a polyol based on ethylene glycol reacted with propylene oxide claim 1 , or a polyol based on ethylene glycol reacted with ethylene oxide and propylene oxide claim 1 , or mixtures thereof.6. The process of wherein the alcohol is a polyol based on glycerol reacted with ethylene oxide claim 1 , a polyol based on glycerol reacted propylene oxide claim 1 , a polyol based on glycerol reacted butylene oxide claim 1 , a polyol based on glycerol reacted ethylene oxide and/or propylene oxide and/or butylene oxide claim 1 , or mixtures thereof.7. The process of wherein the alcohol is ethylene glycol claim 1 , diethylene glycol claim 1 , triethylene glycol claim 1 , tetraethylene glycol claim 1 , glycerol claim 1 , polyethylene glycol claim 1 , polypropylene glycol claim ...

Upgraded ebullated bed reactor with no recycle buildup of asphaltenes in vacuum bottoms

An ebullated bed hydroprocessing system is upgraded using a dual catalyst system that includes a heterogeneous catalyst and dispersed metal sulfide particles, which permits recycling of vacuum bottoms without recycle buildup of asphaltenes. The dual catalyst system more effectively converts asphaltenes in the ebullated bed reactor and increases asphaltene conversion by an amount that at least offsets higher asphaltene concentration resulting from recycling of vacuum bottoms. In this way, there is no recycle buildup of asphaltenes in upgraded ebullated bed reactor notwithstanding recycling of vacuum bottoms. In addition, residual dispersed metal sulfide catalyst particles in the vacuum bottoms can maintain or increase the concentration of the dispersed metal sulfide catalyst in the ebullated bed reactor.

HEAVY AROMATIC SOLVENTS FOR CATALYST REACTIVATION

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 ...

Use of Solvent to Decrease Caustic Scrubber Fouling

A method of reducing the formation of fouling deposits occurring in a caustic scrubber used to remove acid gases can include providing a caustic scrubber fed with an alkaline aqueous solution including essentially one or more of NaOH, KOH or LiOH. The method can include providing an olefin-containing hydrocarbon stream that is contaminated with oxygenated compounds and acid gases. The oxygenated compounds can be capable of making polymeric fouling deposits in the presence of the alkaline solution of the scrubber. The method can include sending the hydrocarbon stream to the caustic scrubber to recover an olefin-containing hydrocarbon stream that is essentially free of acid gases. An efficient amount of a solvent capable of reducing the formation of fouling deposits can be introduced in the caustic scrubber and/or in the alkaline solution fed to the scrubber. The solvent can be separated from the alkaline solution.

Method and kit for treatment of components utilized in a crude oil service operation

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.

Solid Drag Reduction Additive and Method of Using Same

Methods of reducing drag in a flowing hydrocarbon include introducing to the flowing hydrocarbon an amount of a solid drag reducing additive effective to improve the flow, the solid drag reducing additive including a polymer particle prepared from at least one polar monomer and a percent by weight (wt %) of liquid of 50 wt % or less. Methods also include producing a solid drag reducing additive that includes forming a polymer from at least one polar monomer by emulsion polymerization; and disrupting the emulsion by adding at least one demulsifier and at least one anti-blocking agent to form the solid drag reducing additive. Compositions include a solid drag reducing additive comprising a polymer prepared from at least one polar monomer and having an average particle size in a range of about 100 μm to about 500 μm, wherein the solid drag reducing additive comprises less than 50 wt % of liquid. 1. A method of reducing drag in a flowing hydrocarbon , comprising:introducing to the flowing hydrocarbon an amount of a solid drag reducing additive effective to improve the flow, the solid drag reducing additive comprising a polymer particle prepared from at least one polar monomer and a percent by weight (wt %) of an aqueous fluid of 50 wt % or less.2. The method of wherein the percent by weight (wt %) of the aqueous fluid is 10 wt % or less.3. The method of claim 1 , wherein the flowing hydrocarbon has an API gravity of 26 or less.4. The method of claim 1 , wherein the solid drag reducing additive has an average particles size in a range of about 100 μm to about 500 μm.6. The method of claim 1 , wherein the polar monomer comprises a branched alkyl substituent.7. The method of claim 1 , wherein the solid drag reducing additive is added to the flowing hydrocarbon at a parts per million by weight of about 10 ppmw to 100 ppmw.8. The method of claim 1 , wherein introducing comprises adding the solid drag reducing additive by gravity feed to the flowing hydrocarbon.9. The method ...

CATALYTIC COATINGS, METHODS OF MAKING AND USE THEREOF

Described herein are coatings. The coatings can, for example, catalyze carbon gasification. In some examples, the coatings comprise: a first region having a first thickness, the first region comprising manganese oxide, a chromium-manganese oxide, or a combination thereof, and CaWO, BaYWO, or a combination thereof; a second region having a second thickness, the second region comprising XWZ, XWZ, or a combination thereof, wherein X is independently Ni or a mixture of Ni and one or more transition metals and Z is independently Si, C, or a combination thereof. In some examples, the coatings further comprise a rare earth element, a rare earth oxide, or a combination thereof. 1. A coating comprising:{'sub': 4', '3', '2', '9, 'a first region having a first thickness, the first region comprising a manganese oxide, a chromium-manganese oxide, or a combination thereof, and CaWO, BaYWO, or a combination thereof;'}{'sub': 6', '6, 'a second region having a second thickness, the second region comprising XWZ, XWZ, or a combination thereof, wherein X is independently Ni or a mixture of Ni and one or more transition metals and Z is independently Si, C, or a combination thereof; and'}a rare earth element, a rare earth oxide, or a combination thereof.2. The coating of claim 1 , wherein the second region comprises Mn in an amount of from 3 wt % to 15 wt % claim 1 , based on the total weight of the second region.3. (canceled)4. The coating of claim 1 , wherein the second region comprises Si in an amount of from 1 wt % to 10 wt % claim 1 , based on the total weight of the second region.5. (canceled)6. (canceled)7. A coating comprising:{'sub': 4', '3', '2', '9, 'a first region having a first thickness, the first region comprising a manganese oxide, a chromium-manganese oxide, or a combination thereof, and CaWO, BaYWO, or a combination thereof; and'}{'sub': 6', '6, 'a second region having a second thickness, the second region comprising XWZ, XWZ, or a combination thereof, wherein X is ...

METHOD FOR REMOVING FOULING DOWNSTREAM OF AN ODH REACTOR

A method for preventing or removing water soluble fouling located downstream of an oxidative dehydrogenation (ODH) reactor is described. The method employs the introduction of water upstream of fouling locations, either continuously or intermittently, which acts to solubilize and carry away fouling material. The method has the advantage of being applicable for use while an ODH process is ongoing, circumventing the need for a costly shutdown. 1. A method for removing or preventing buildup of substantially water soluble fouling in the piping downstream of an idle or operational ODH reactor , comprising introducing a solvent into one or more locations within said piping , with at least one of said one or more locations at a position upstream of fouling or where fouling is likely to develop , and wherein the solvent is introduced primarily in a liquid state at the pressure and temperature within said piping at the location of introduction.2. The method of wherein the solvent is introduced at a flow rate or pressure that promotes an annular flow of solvent substantially in contact with the inner surface of said piping.3. The method of wherein the ODH reactor is operational and the solvent is introduced at a flow rate or pressure that promotes slug flow of the solvent and wherein the introduction of the solvent does not disrupt operation of said ODH reactor.4. The method of wherein the solvent is water.5. The method of wherein the solvent is water.6. The method of wherein the solvent is water.7. The method of wherein the solvent is dilute acetic acid.8. The method of wherein the solvent is dilute acetic acid.9. The method of wherein the solvent is dilute acetic acid.10. The method of wherein the solvent is introduced into at least one of said one or more locations via a pipe in pipe arrangement.11. The method of wherein the solvent is water.12. The method of wherein the solvent is dilute acetic acid.13. The method of wherein the solvent is introduced into at least one of ...

Burner, Furnace, and Steam Cracking Processes Using the Same

A burner sub-system, a furnace comprising the same, a fuel combustion process and steam cracking process carried out in the furnace. The burner sub-system comprises a barrier wall segment between the burner tip and the flue-gas recirculation (“FGR”) duct, effectively blocking direct gas flow between the burner tip and the FGR duct opening, but without encircling the whole burner tip. The presence of the partial barrier wall has the advantage of preventing the temperature inside the FGR duct from becoming too high, while achieving low NOx emissions from the combustion process without overheating the burner tip because of reduced amount of heat reflection to the burner tip compared to an annular barrier wall. The invention is particularly useful in furnaces where hydrogen-rich fuel gas is combusted. 110-. (canceled)111. A furnace comprising at least one burner sub-system according to claim , further comprising:a furnace floor comprising the furnace floor segment of each of the at least one burner sub-system; andone or more furnace side walls;wherein the furnace floor and the one or more furnace side walls form a furnace fire box.12. The furnace of claim 11 , wherein the distance from the vertical centerline of any burner tip to any side wall is at least 30 centimeters.13. The furnace of claim 11 , which comprises multiple burner sub-systems and is free of any partitioning wall between adjacent burner sub-systems.14. The furnace of claim 11 , wherein the fire box has a height of at least 10.5 meters.15. The furnace of claim 11 , wherein the fire box has a height of at least 15.0 meters.16. The furnace of claim 11 , further comprising multiple side wall burners configured to produce at least one side wall burner flame from at least one of the furnace side walls.17. The furnace of claim 11 , which is free of a side wall burner configured to produce a side wall burner flame from any of the furnace side wall.18. The furnace of claim 11 , comprising at least three burner ...

Method to inhibit polymerization in a process water

Disclosed herein are methods for reducing fouling caused by process water present within a water recycling loop of a pyrolysis plant. Fouling is caused by phase separation and accumulation of materials from the process water on equipment surfaces. The method includes applying a total of about 5 ppm to 500 ppm total of a first polymerization inhibitor and second polymerization inhibitor to the process water to form a treated process water, wherein the first polymerization inhibitor has a pygas-water partition coefficient of about 0.0001 to 9 and the second polymerization inhibitor has a pygas-water partition coefficient of about 1000 to 50,000.

ONLINE ZETA-POTENTIAL MEASUREMENTS FOR OPTIMIZATION OF EMULSION BREAKER DOSAGE IN ETHYLENE PLANTS

A method for treating an emulsion emanating from a quenching process in production of ethylene that includes online monitoring of zeta potential of the hydrocarbon/water emulsion in a quench water tower and/or a quench water loop. In response to the online monitoring of zeta potential, the method changes the amount of demulsifier being added to the hydrocarbon/water emulsion such that the amount of demulsifier is effective in breaking the emulsion. 1. A method for treating an emulsion emanating from a quenching process in production of ethylene , the method comprising:adding a demulsifier to a hydrocarbon/water emulsion in a quench water tower and/or a quench water loop in use for ethylene production;online monitoring of zeta potential of the hydrocarbon/water emulsion in the quench water tower and/or the quench water loop; andin response to the online monitoring of zeta potential, changing the amount of demulsifier being added to the hydrocarbon/water emulsion such that the amount of demulsifier is effective in breaking the emulsion.2. The method of claim 1 , wherein the amount of demulsifier is changed so that the zeta potential of the emulsion is within a range of −30 to +30 mV.3. The method of claim 1 , wherein the amount of demulsifier is changed so that the zeta potential of the emulsion is within a range of −5 to +5 mV.4. The method of claim 1 , further comprising:monitoring of one or more physicochemical parameters of a hydrocarbon stream flowing into the quench water tower.5. The method of claim 4 , wherein the one or more physicochemical parameters is selected from the list consisting of: boiling point claim 4 , critical point claim 4 , surface tension claim 4 , and vapor pressure.6. The method of claim 4 , further comprising:in response to the monitoring of the one or more physicochemical parameters and the online monitoring of zeta potential, changing the amount of demulsifier being added to the hydrocarbon/water emulsion such that the amount of ...

N,N-DIMETHYLACETAMIDE AS WASH-OIL FOR DILUTION STEAM SYSTEMS

A method of removing material that fouls processing equipment that includes applying a composition comprising N,N-dimethylacetamide (DMAC) to fouling material deposited on the processing equipment to solubilize and remove the fouling material from the processing equipment. 1. A method of removing material that fouls processing equipment , the method comprising applying a composition comprising N ,N-dimethylacetamide (DMAC) to fouling material deposited on the processing equipment to solubilize and remove the fouling material from the processing equipment.2. The method of claim 1 , wherein the processing equipment is used in production of ethylene.3. The method of claim 1 , wherein the fouling material comprises polystyrene or other aromatic fouling material.4. The method of claim 3 , wherein the processing equipment comprises a dilution steam system used in production of ethylene.5. The method of claim 4 , wherein the processing equipment is a quench water tower claim 4 , a quench water settler claim 4 , a quench water loop claim 4 , a process water stripper claim 4 , a heat exchanger claim 4 , or a pump.6. The method of claim 4 , further comprising continuously or intermittently dosing the composition to a feed of the dilution steam system before applying the composition to the fouling material.7. The method of claim 1 , wherein the composition is applied by flushing the processing equipment with the composition claim 1 , spraying the processing equipment with the composition claim 1 , brushing the processing equipment with the composition claim 1 , or adding the composition to a dilution steam generator feed.8. The method of claim 7 , wherein the applying of the composition comprises spraying the composition on the fouling material.9. The method of claim 1 , wherein the composition is applied to the processing equipment intermittently.10. The method of claim 9 , wherein intermittent application comprises substantially the same period of time between applications ...

Heat Recovery for Bitumen Froth Treatment Plant Integration with Sealed Closed-Loop Cooling Circuit

A system and process for recovering heat from a bitumen froth treatment plant use a sealed closed-loop heat transfer circuit. The system has a heat removal exchanger associated with the plant and receiving hot froth treatment process stream; heat recovery exchanger; the circuit; and an oil sands process fluid line. The circuit includes piping circulating heat exchange media having uncontaminated and low fouling properties. The piping includes a supply line to the heat removal exchanger and a return line for providing heated media to the recovery exchanger. The circuit has a pump for pressurizing the heat exchange media; a pressure regulator for regulating pressure of the media. The pump and the pressure maintain the media under pressure in liquid phase. The oil sands process fluid is heated producing a cooled media for reuse in the heat removal exchanger. High and low temperature heat removal exchangers can be used.

Termination Device of a Reactor of a Fluid Catalytic Cracking Unit

The invention relates to a termination device () of a tubular reactor () comprising at least one separation element () adapted for the separation of solid particles and gaseous effluents and at least one coupling element () that is part of an end of said tubular reactor, said separation element being connected to said coupling element, characterized in that each element of the termination device is made of ceramic material. 114.-. (canceled)15. A termination device of a tubular reactor comprising:{'sub': 4', '3', '4', '2', '3, 'at least one separation element adapted for the separation of solid particles and gaseous effluents and at least one coupling element that is part of an end of the tubular reactor, the separation element being connected to the coupling element, characterized in that each element of the termination device is made of ceramic material and the ceramic material comprises a ceramic matrix selected from silicon carbide SiC, boron carbide BC, silicon nitride SiN, aluminium nitride AlN, boron nitride BN, alumina AlO, or mixtures thereof, incorporated in which ceramic matrix are carbon fibres or ceramic fibres.'}16. The termination device according to claim 15 , characterized in that the ceramic fibres are selected from the group consisting of crystalline alumina fibres claim 15 , mullite fibres claim 15 , crystalline or amorphous silicon carbide fibres claim 15 , zirconia fibres claim 15 , silica-alumina fibres claim 15 , and mixtures thereof17. The termination device according to claim 15 , characterized in that the ceramic material is a sintered ceramic material.18. The termination device according to claim 15 , characterized in that the ceramic material is a Ceramic Matrix Composite (CMC).19. The termination device according to claim 15 , characterized in that the elements form one and the same part made of ceramic material.20. The termination device according to claim 15 , characterized in that the elements are separate elements made of ceramic ...

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

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. 1. A method of optimizing a system parameter in a process stream of a crude unit to reduce corrosion and/or corrosion byproduct deposition in the crude unit , the method comprising:(a) measuring and/or predicting a property associated with the system parameter at one or more points in the crude unit;(b) determining an optimum range associated with the measured and/or predicted property;(c) 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; and(d) optionally repeating steps (a) to (c) for a plurality of different system parameters, each different system parameter having a unique associated property.2. The method of claim 1 , including: (i) converting the measured property into an input electrical signal capable of being transmitted to a controller and (ii) transmitting the input electrical signal to the controller.3. The method of claim 2 , including transmitting the input electrical signal via a wireless interface.4. ...

A COMPOSITION, METHOD AND APPLICATIONS THEREOF

The instant disclosure relates to a composition comprising potassium carbonate and calcium acetate, optionally along with sulfur containing compound. The composition of the present disclosure reduces coke formation during hydrocarbon cracking, particularly reduces surface coke and spalled coke during hydrocarbon cracking when compared to hydrocarbon cracking without the said composition. The disclosure further relates to a method for reducing formation and/or deposition of coke during pyrolysis or cracking of hydrocarbons. 1. A composition comprising alkali metal salt and alkaline metal salt , optionally along with sulfur containing compound , wherein the composition reduces coke formation during hydrocarbon cracking.2. The composition as claimed in claim 1 , wherein the alkali metal salt is potassium carbonate and alkaline earth metal salt is calcium acetate; wherein the concentration of the potassium carbonate and the calcium acetate is ranging from about 1 ppmw to 4 ppmw; and wherein in the said concentration claim 1 , the potassium carbonate is about 35 wt % and the calcium acetate is about 65 wt %.3. The composition as claimed in claim 1 , wherein the sulfur containing compound is selected from a group comprising dimethyl disulfide claim 1 , dimethyl sulfide claim 1 , diethyl sulfide claim 1 , diethyl disulfide carbon disulfide and dimethyl sulfoxide claim 1 , or any combination thereof claim 1 , and concentration of the sulfur containing compound is ranging from about 50 ppmw to 250 ppmw.4. The composition as claimed in claim 1 , wherein the composition is soluble in water and polar solvent claim 1 , independently.5. The composition as claimed in claim 1 , wherein the composition reduces coke formation by at least 40% during hydrocarbon cracking when compared to the hydrocarbon cracking without the composition; wherein the composition reduces surface coke by at least 60% during hydrocarbon cracking when compared to the hydrocarbon cracking without the ...

Retractable nozzle for refractory-lined equipment

A refractory-lined equipment includes a vessel defining an interior at least partially lined with a refractory material, and a nozzle assembly coupled to the vessel and extending into the interior. The nozzle assembly includes an outer sleeve fixed to the sidewall and extending through an aperture defined in the sidewall, the outer sleeve defining a central passageway, and a nozzle cartridge assembly positionable within the central passageway and including an inner sleeve, a refractory lining disposed about the inner sleeve, and a nozzle positioned within the inner sleeve. The nozzle cartridge assembly is removably coupled to the outer sleeve external to the vessel.

CLEANING PROCESS TO REMOVE RED OILS DEPOSITS IN AN INSTALLATION COMPRISING FATTY ACID ESTERS AS CLEANING AGENT AND USE OF FATTY ACID ESTERS AS CLEANING AGENT IN SUCH A PROCESS

The invention relates to a process for removing red oils deposits formed in an installation comprising the use of a cleaning agent comprising one or more fatty acid esters to dissolve the red oils deposit and to form a mixture comprising the cleaning agent and the dissolved red oils; and removing the mixture comprising the cleaning agent and the dissolved red oils. 116.-. (canceled)17. A process for removing red oils deposits formed in an installation comprising:b) adding a cleaning agent comprising one or more fatty acid esters;c) circulating the cleaning agent within the installation to dissolve the red oils deposit in the cleaning agent and to form a mixture comprising the cleaning agent and the dissolved red oils; andd) removing the mixture comprising the cleaning agent and the dissolved red oils.18. The process of claim 17 , further comprising a step a) of washing the installation to remove a soda excess that is performed before the step b) of addition of the cleaning agent claim 17 , preferably in step a) washing is performed with water.19. The process of wherein in step b) claim 17 , the one or more fatty acid esters comprises fatty acid methyl esters claim 17 , fatty acid ethyl esters or any mixture thereof; preferably in step b) the one or more fatty acid esters comprise fatty acid methyl esters.20. The process of wherein in step b) claim 17 , the cleaning agent is a biodiesel.21. The process of wherein in step b) claim 17 , the one or more fatty acid esters added have a carbon chain length ranging from 4 to 36 carbon atoms.22. The process of wherein in step b) claim 17 , the one or more fatty acid esters have a flash point above 50° C.23. The process of wherein step c) is performed at a temperature ranging from 0 to 150° C.24. The process of wherein step c) is performed by recirculating pumps and/or by high-pressure injectors and/or gas bubbling.25. The process of wherein in step c) is performed during installation shutdown or operation claim 17 , ...

METHOD FOR UPGRADING A HYDROCARBON FEED

A method for upgrading a hydrocarbon feed is disclosed. The method may be carried out in a pyrolysis furnace that may have at least two coils and at least two thermal zones. The method may include two operating or run modes that may be repeated in a cycle. In one run, upgrading may be carried out in one coil while decoking may be carried out in the other coil. After a predetermined amount of time, the streams of the two coils may be switched for a second run, such that decoking may be carried out in the coil in which upgrading was done in the first run and upgrading may be carried out in the coil in which decoking was done in the first run. The first and the second run are cyclically repeated one after the other. 1. A method for upgrading a hydrocarbon feed in a pyrolysis furnace. the method comprising:associating at least a first coil with a first thermal zone of the pyrolysis furnace;associating at least a second coil with a second thermal zone of the pyrolysis furnace, the second thermal zone being spaced apart from the first thermal zone; and upgrading a first hydrocarbon feed in the second coil;', 'feeding a first steam stream to the first coil, thereby heating the first steam stream; and', 'decoking the first coil., 'operating the pyrolysis furnace in a first mode, the first mode comprising2. The method of claim 1 , wherein operating the pyrolysis furnace in the first mode further comprises:mixing the first steam stream from the first coil with the first hydrocarbon feed in the first thermal zone, thereby producing a combined first hydrocarbon/steam stream; andfeeding the first hydrocarbon/steam stream to the second coil in the second thermal zone.3. The method of claim 2 , further comprising: upgrading a second hydrocarbon feed in the first coil;', 'feeding a second steam stream to the second coil, thereby heating the second steam stream; and', 'decoking the second coil., 'operating the pyrolysis furnace in a second mode. the second mode comprising4. The ...

Steam Cracker Product Fractionation

The invention generally relates to processes for separating steam cracker products by fractional distillation, and to systems and apparatus useful in such processes. More specifically, the invention relates to decreasing the amount of fractionator fouling that can result from increasing the amount of hydrocarbon molecules in the steam cracker feed having four or fewer carbon atoms. 122-. (canceled)21. A steam cracking apparatus , comprising:{'sub': '2+', '(a) at least one steam cracking furnace which includes (i) a convection section having at least one convection coil, the convection section being configured for combining the steam and a C hydrocarbon feed to produce a steam cracker feed, and for heating the steam cracker feed, and (ii) a radiant section having at least one radiant coil, wherein the radiant coil is in fluidic communication with the convection coil and is configured for receiving and cracking the heated steam cracker feed to produce a steam cracker effluent that is at least partially vapor phase;'} (i) receiving steam cracker effluent from the radiant coil and', '(ii) cooling the steam cracker effluent sufficiently to condense a portion of the vapor phase steam cracker effluent into the liquid phase;, '(b) a first cooling stage located downstream of the steam cracker furnace, the first cooling stage being in fluidic communication with the radiant coil and being configured for'}(c) at least one fractionator located downstream of cooling stage and in fluidic communication with the cooling stage, the fractionator being configured for receiving the cooled steam cracker effluent and for separating at least the vapor phase and liquid phase from the cooled steam cracker effluent;{'sub': '5+', '(d) a second cooling stage in fluidic communication with the fractionator, the second cooling stage being configured for receiving the separated vapor phase and condensing from the vapor phase at least a steam cracker naphtha comprising diolefin and C hydrocarbon;'}( ...

Molecular enhanced based surface enhanced raman spectroscopy to detect low concentration of monoethanolamine

A system and method for estimating a concentration of monoethanolamine (MEA) in a fluid. A substrate for supporting a sample of the fluid during testing includes a carbon nanotube mat layer, a silver nanowire layer disposed on the carbon nanotube mat layer, and a chemical enhancer layer disposed on the silver nanowire layer. A sample of the fluid is placed on the substrate, and the fluid sample is radiated with electromagnetic radiation at a selected energy level. A detector measures a Raman spectrum emitted from the sample in response to the electromagnetic radiation. A processor estimates the concentration of MEA in the sample from the Raman spectrum and adds a corrosion inhibitor to the fluid in an amount based on the estimated concentration of MEA to reduce the concentration of MEA in the fluid.

METHOD AND COMPOSITION FOR NEUTRALIZING ACIDIC COMPONENTS IN PETROLEUM REFINING UNITS

A method of inhibiting corrosion and fouling in petroleum refining units which comprises adding choline hydroxide either alone or in combination with a hydrogen-bond donor such as a carboxylic acid, an amine, an amide, or an alcohol. 1. A process for neutralizing acidic components in an overhead system of a refining unit comprising water condensate and petroleum products comprising the step of adding to the system a neutralizing amount of a neutralizing composition comprising a solution of choline hydroxide.2. The process of further comprising the step of adding one or more hydrogen-bond donor.3. The process of wherein the choline hydroxide and the hydrogen bond donor are added together in the solution.4. The process of wherein the solution of choline hydroxide and the hydrogen bond donor are added to the system separately.5. The process of wherein the one or more hydrogen bond donor is a carboxylic acid claim 2 , an amine claim 2 , an amide claim 2 , or an alcohol.6. The process of wherein the hydrogen bond donor is glycerol claim 2 , ethylene glycol claim 2 , urea claim 2 , acetamide claim 2 , thiourea claim 2 , m-cresol claim 2 , or phenol.7. The process of wherein the hydrogen bond donor is glycerol or ethylene glycol.8. The process of further comprising the step of adding one or more alkylamine or alkanolamine.9. The process of wherein the alkylamine or alkanolamine is dimethylethanolamine (DMEA) claim 8 , dimethylisopropanolamine (DMIPA) claim 8 , ethylenediamine (EDA) claim 8 , methoxypropylamine (MOPA) claim 8 , monoethanolamine (MEA) claim 8 , dimethylaminopropylamine (DMAPA) claim 8 , morpholine claim 8 , or trimethylamine (TMA).10. The process of wherein the amount of the neutralizing composition ranges from 1 to 10 claim 1 ,000 ppm based on the petroleum products.11. The process of further comprising the step of adding the neutralizing composition to the system at a rate sufficient to maintain the pH of water condensate in the system at a pH of equal to ...

Burner, Furnace, and Steam Cracking Processes Using the Same

A burner sub-system, a furnace comprising the same, a fuel combustion process and steam cracking process carried out in the furnace. The burner sub-system comprises a barrier wall segment between the burner tip and the flue-gas recirculation (“FGR”) duct, effectively blocking direct gas flow between the burner tip and the FGR duct opening, but without encircling the whole burner tip. The presence of the partial barrier wall has the advantage of preventing the temperature inside the FGR duct from becoming too high, while achieving low NOx emissions from the combustion process without overheating the burner tip because of reduced amount of heat reflection to the burner tip compared to an annular barrier wall. The invention is particularly useful in furnaces where hydrogen-rich fuel gas is combusted. 1. A burner sub-system comprising:a furnace floor segment having a floor burner opening and a flue-gas recirculation duct opening;a tile enclosure lining the periphery of the floor burner opening;a burner comprising a burner tip adjacent and surrounded by the floor burner opening, the burner tip having a vertical centerline and configured to provide a floor burner flame through the floor burner opening;a flue-gas recirculation duct opening adjacent the tile; anda barrier wall segment extending upwards from the upper surface of the furnace floor segment between the flue-gas recirculation duct opening and the burner tip, the barrier wall segment having an angle of view no greater than 180° when viewed from the point where the vertical centerline of the burner tip intercepts a plane of the furnace floor segment.2. The burner sub-system of claim 1 , wherein the barrier wall segment has an angle of view no more than 90° when viewed from the point where the vertical centerline of the burner tip intercepts a plane of the furnace floor segment.3. The burner sub-system of claim 1 , wherein the barrier wall segment blocks at least 50% of the line of sight of the flue-gas ...

Naphthenic acid corrosion inhibitors for a refinery

Corrosion inhibitor compositions and methods for inhibiting corrosion on a metal surface exposed to a hydrocarbon fluid are provided. The corrosion inhibition compositions can include a corrosion inhibitor, such as 3-dimethylamino benzoic acid, 4-dimethylamino benzoic acid, or 2,5-dihydroxyterephthalic acid. The corrosion inhibitor composition can further comprise dimethyl sulfoxide, and heavy aromatic naphtha. The corrosion inhibitor composition can be phosphate-free and can inhibit naphthenic acid corrosion. In the methods, a corrosion inhibitor composition is added to the hydrocarbon fluid exposed to the metal surface to prevent or inhibit corrosion on the metal surface, including naphthenic acid corrosion.

METHOD FOR ACCELERATING FOULING OF INJECTORS IN GASOLINE DIRECT INJECTION ENGINES AND FOR EVALUATING PERFORMANCE OF DEPOSIT CONTROL ADDITIVES

A method for fouling an injector of a gasoline direct injection engine, includes the steps of operating the direct injection engine on at least a first stationary engine mode which is defined by a pre-established engine load and a pre-established engine speed. Both the pre-established engine load and the speed are within 35% and 65% of their maximum values, this at least first stationary engine mode being characterized by high particulate matter generation. The direct injection engine is operated on the at least first engine mode for less than ten hours. 2. The method according to claim 1 , wherein operating the direct injection engine comprises alternating operation of the direct injection engine between a first stationary engine mode and a second stationary engine mode claim 1 , each engine mode being defined by a pre-established engine load and a pre-established engine speed claim 1 , both the pre-established engine load and speed being comprised within 35% and 65% of their maximum values and being characterized by high particulate matter generation.3. The method according to claim 2 , wherein the GDI engine starts operating at the engine mode having the highest engine load.4. The method according to claim 2 , which further comprises continuously monitoring the particulate matter emission.5. The method according to claim 1 , which further comprises continuously monitoring the injection duration of the injector using external current or voltage measuring means.6. The method according to claim 1 , wherein the direct injection engine is operated for less than eight hours claim 1 , preferably during six hours.7. The method according to claim 2 , wherein the direct injection engine is operated in the first stationary engine mode and in the second stationary engine mode during time intervals of the same duration.8. The method according to claim 2 , wherein the first stationary engine mode and in the stationary second engine mode are operated during time intervals claim ...

METHOD OF REDUCING CORROSION AND CORROSION BYPRODUCT DEPOSITION IN A CRUDE UNIT

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. 118-. (canceled)19. A system for controlling chloride ion concentrations in a process stream of a crude unit to reduce corrosion and/or corrosion byproduct deposition in the crude unit , the system comprising:(a) a sensing device operable to sense and/or predict the chloride ion concentrations over time and convert the sensed or predicted chloride ion concentrations into input electrical signals capable of being transmitted, wherein the sensed and/or predicted chloride ion concentrations over time include a variation comprising chloride ion concentration spikes, and wherein the sensing device is operable to sense and/or predict the chloride ion concentrations at a frequency that shows the chloride ion concentration spikes over time;(b) a transmitter operable to transmit the input electrical signals;(c) a controller operable to receive the transmitted input electrical signals, convert the received input electrical signals into input numerical values, analyze the input numerical values, determine if the analyzed input numerical values are within an optimum range, generate output numerical values based upon the analyzed values, convert the output numerical values into output electrical signals, and transmit the ...

APPARATUS EXPOSBLE IN BYPRODUCE CARCONACEOUS MATERIAL FORMATION ENVIRONMENT AND ASSOCIATED METHOD

An apparatus has a surface exposable to a byproduct carbonaceous material formation environment and comprising a perovskite material having an ABOperovskite structure and being of formula ABO, wherein 0.9 Подробнее

NOVEL ORGANIC ACID SYSTEMS

An organic acid composition for use in oil industry activities, said composition comprising an arylsulfonic acid in water as well as the use of said composition to perform various operations in the oil industry. There is also disclosed a solid acid composition comprising a corrosion inhibitor ready for dissolution and use.

CONTAMINANT REMOVAL METHOD FOR FRACTIONATING COLUMNS

Methods for removing water and/or dissolved and solid contaminants from a liquid hydrocarbon such as condensate flowing through a fractionating column are disclosed. Pressure within the column and temperature at which the reboiler operates are observed to prevent boiling of the contaminated hydrocarbon thus obviating contaminant deposition on heated surfaces. Further methods directed to column operation and anti-fouling procedures augment the core method. Apparatus to effect the methods is also provided. 1. A method of extracting contaminants from a feed stream containing liquid hydrocarbons , contaminants and water , comprising:providing a fractionating circuit;passing said feed stream into said fractionating circuit;maintaining pressure and temperature in said circuit at levels suitable to prevent boiling of said feed stream;isolating water, contaminant and mixtures thereof from said liquid hydrocarbons; andremoving isolated water, contaminant and mixtures thereof from said circuit.2. The method as set forth in claim 1 , further including the step of providing a separator in said circuit for separating liquid hydrocarbons claim 1 , contaminant and water.3. The method as set forth in claim 1 , further including the step of introducing fresh water at predetermined positions in said circuit.4. The method as set forth in claim 2 , further including the step of recycling contaminant rich water from said separator into said feed stream to be treated.5. The method as set forth in claim 1 , further including the step of introducing an additive to increase contaminant solubility in said feed stream.6. The method as set forth in claim 1 , further including the step of treating mechanical components in said fractionating circuit to reduce contaminant accretion.7. The method a set forth in claim 6 , wherein treating includes at least one of chemical and mechanical treatment8. The method as set forth in claim 1 , further including the step of operating a fractionating column ...

AMINATION OF POLYMERS TERMINATED WITH ALDEHYDE GROUP AND THEIR FUNCTIONALIZED DERIVATIVES FOR FOULING MITIGATION IN HYDROCARBON REFINING PROCESSES

A compound useful for reducing fouling in a hydrocarbon refining process is provided. A method for preparing the compound includes converting a polymer having a vinyl chain end to obtain an aldehyde 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 side ...

DIRECT FLAME IMPINGEMENT SHIELD

Described are direct flame impingement shields for fire tubes in heater treaters which reduce corrosion of the fire tubes. The direct flame impingement shield is removable and replaceable. The direct flame impingement shield may be formed from a variety of types of stainless steel or other corrosion resistant material. 1. A direct flame impingement shield comprising:a barrier tube;a tapered end portion on a back end of the barrier tube;a flared end portion on a front end of the barrier tube;a cross member internally positioned towards the front end of the barrier tube; anda leveling member externally positioned towards the back end of the barrier tube.2. The direct flame impingement shield of claim 1 , wherein the barrier tube claim 1 , the tapered end portion claim 1 , the flared end portion claim 1 , the cross member and the leveling member are formed from a corrosion resistant material.3. The direct flame impingement shield of claim 2 , wherein the corrosion resistant material is selected from the group consisting of modified stainless steel claim 2 , hybrid stainless steel claim 2 , blended stainless steel claim 2 , carbon steel and/or mixtures thereof.4. The direct flame impingement shield of claim 1 , wherein an end of the flared end portion is wider than the barrier tube.5. A fire tube for a heater treater comprising:a direct flame impingement shield, the direct flame impingement shield comprising:a barrier tube;a tapered end portion on a back end of the barrier tube;a flared end portion on a front end of the barrier tube;a cross member internally positioned towards the front end of the barrier tube; anda leveling member externally positioned towards the back end of the barrier tube, wherein the direct flame impingement shield is removably coupled to the fire tube.6. The fire tube of claim 5 , wherein the direct flame impingement shield extends over a portion of a length the fire tube.7. The fire tube of claim 5 , wherein the direct flame impingement shield ...

EROSION MONITORING SYSTEM FOR COMPONENTS FOR FLUID BED CATALYTIC CRACKING PLANTS

An erosion monitoring system of components exposed to wear for use in systems equipped with a fluidized catalyst comprising a bundle of fiber optic sensors, said optical fibers being provided with one or more Bragg gratings, a processing unit and the fiber optic sensors depart off from the bundle and are positioned transversely to the wall exposed to erosion wear due to the erosion of the components to be monitored.

Effective Novel Non-Polymeric and Non-Fouling Additive for Inhibiting High-Temperature Naphthenic Acid Corrosion and Method of Using the Same

The present invention relates to inhibition of high temperature naphthenic acid corrosion occurring in hydrocarbon processing units. The invention provides an effective novel non-polymeric and non-fouling additive for inhibiting high-temperature naphthenic acid corrosion, comprising an effective corrosion-inhibiting amount of a second phosphate ester wherein said second phosphate ester is obtained by reacting a first phosphate ester with an oxirane compound selected from the group consisting of butylene oxide, ethylene oxide, propylene oxide or any other oxirane compound or a combination thereof, preferably with butylene oxide, capably yielding said second phosphate ester, having a structure A or B, 2. The process as claimed in claim 1 , wherein said stream includes crude oil claim 1 , feedstock claim 1 , and hydrocarbon stream and/or fractions thereof.3. The process as claimed in claim 1 , wherein the additive has acidity varying from about 1 mg KOH/gm to about 20 mg KOH/gm.4. The process as claimed in claim 1 , wherein the additive has phosphorus contents varying from about 0.5% to about 9% of said additive.5. The process as claimed in claim 1 , wherein mole ratios of said phosphorus pentoxide and said alcohol are used claim 1 , such that the mole ratio of said phosphorus pentoxide to said alcohol is 1 mole of said phosphorus pentoxide to 1 to 10 mole of said alcohol and 1 mole of said phosphorus pentoxide to 1 to 7 mole of said alcohol.7. The method as claimed in claim 6 , wherein the additive has acidity varying from about 1 mg KOH/gm to about 20 mg KOH/gm.8. The method as claimed in claim 6 , wherein the additive has phosphorus contents varying from about 0.5% to about 9% of said additive.9. The method as claimed in claim 6 , wherein mole ratios of said phosphorus pentoxide and said alcohol are used claim 6 , such that the mole ratio of said phosphorus pentoxide to said alcohol is 1 mole of said phosphorus pentoxide to 1 to 10 mole of said alcohol and 1 mole of ...

Systems comprising bonded layer utilized in a crude oil service operation

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 bonded layer coating, and may also include contacting the surface with the contaminant, wherein the contaminant is selected from the group consisting of paraffins and asphaltenes, and wherein the bonded layer is a molecularly bonded layer or a covalently bonded layer. Various systems include one having a liquid environment of paraffins and asphaltene, and a surface residing within the environment comprising a bonded layer composition. Systems also include pipelines and vessels having an internal surface therein comprising a bonded layer composition, and with hydrocarbon liquids present in the pipeline or vessel.

METHOD FOR REDUCING CORROSIVE IONS IN AROMATIC COMPOUND EXTRACTION SOLVENT

In order to suppress corrosion of an extractor caused by corrosive ions contained in an aromatic compound extraction solvent of a circulation system, a method for reducing corrosive ions in an aromatic compound extraction solvent is provided, by which the corrosive ions in the aromatic compound extraction solvent are conveniently and efficiently reduced. A method for reducing corrosive ions in an aromatic compound extraction solvent in a circulation system where the aromatic compound extraction solvent circulates, the corrosive ions being at least one kind selected from the group consisting of chloride ions, sulfate ions, and sulfite ions, the method comprising: a step of forming a non-volatile salt by adding a corrosive ion scavenger to react the corrosive ions with the corrosive ion scavenger, and a step of removing the salt resulting from concentrating the solvent comprising the salt. 1. A method for reducing corrosive ions in an aromatic compound extraction solvent in a circulation system where the aromatic compound extraction solvent circulates ,the corrosive ions being at least one kind selected from the group consisting of chloride ions, sulfate ions, and sulfite ions,the method comprising:a step of forming a non-volatile salt by adding a corrosive ion scavenger to react the corrosive ions with the corrosive ion scavenger, anda step of removing the salt resulting from concentrating the solvent comprising the salt.2. The method for reducing corrosive ions in an aromatic compound extraction solvent according to claim 1 , wherein the aromatic compound extraction solvent is one or more selected from the group consisting of sulfolane claim 1 , diethylene glycol claim 1 , triethylene glycol claim 1 , tetraethylene glycol claim 1 , N-methylpyrrolidone claim 1 , dimethyl sulfoxide claim 1 , morpholine claim 1 , N-formylmorpholine claim 1 , methyl carbamate claim 1 , diglycolamine claim 1 , furfural claim 1 , and phenol.4. The method for reducing corrosive ions in an ...

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

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. 1. A method of optimizing a system parameter in a process stream of a crude unit to reduce corrosion and/or corrosion byproduct deposition in the crude unit , the method comprising:(a) measuring and/or predicting a property associated with the system parameter at one or more points in the crude unit;(b) determining an optimum range associated with the measured and/or predicted property;(c) 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; and(d) optionally repeating steps (a) to (c) for a plurality of different system parameters, each different system parameter having a unique associated property.2. The method of claim 1 , including: (i) converting the measured property into an input electrical signal capable of being transmitted to a controller and (ii) transmitting the input electrical signal to the controller.3. The method of claim 2 , including transmitting the input electrical signal via a wireless interface.4. ...

REGULATORY CONTROLLER FOR USAGE IN A CATALYTIC OLEFINS

An advanced regulatory controller for a converter of a catalytic olefins unit is disclosed. A Fluid Catalytic Cracking (FCC) type converter (i.e., reactor-regenerator) is combined with an ethylene style cold-end for product recovery. The regulatory controller operates using an Advanced Regulatory Control (ARC) application using variables, such as a controlled variable, four disturbance variables, associated variable, and a manipulated variable. The ARC application manipulates fuel oil or tail gas flow to a regenerator in response to an expected future steady state value of a regenerator bed temperature resulting from changes in the values of a selected set of the variables. 1. A method of controlling a regenerator bed temperature for a catalytic olefins unit , the regenerator receiving at least an olefin feed , a fuel oil , and a tail gas , the method comprising:determining at least one disturbance variable associated with the regenerator, the at least one disturbance variable being selected from one of: (i) an olefin feed rate, (ii) an olefin feed temperature, (iii) a disengager temperature, and (iv) a stripper level;predicting a change in the regenerator bed temperature based on the determined at least one disturbance variable; anddetermining a setpoint for a flow rate of at least one regenerator input to a regenerator based on the predicted change in the regenerator bed temperature, wherein the at least one regenerator input is selected from one of: (i) a fuel oil, and (ii) a tail gas.2. The method of claim 1 , further comprising:determining at least one process input selected from one of: fuel oil flow, tail gas flow, regenerator bed temperature, flue gas oxygen content, and regenerator combustion air rate, wherein the setpoint is also determined based on the determined at least one process input.3. The method of claim 1 , further comprising: determining a gain in the regenerator bed temperature for a change in at least one disturbance variable and a change in ...

Pyrolysis Tar Conversion

This invention relates to a process for determining the suitability of pyrolysis tar, such as steam cracker tar, for upgrading using hydroprocessing without excessive fouling of the hydroprocessing reactor. A pyrolysis tar is sampled, the sample is analyzed to determine one or more characteristics of the tar related to tar reactivity, and the analysis is used to determine conditions under which the tar can be blended, pre-treated, and/or hydroprocessed. 1. A hydrocarbon conversion process , comprising: (i) the first pyrolysis tar contains free radicals and', '(ii) at least 70 wt. % of the first pyrolysis tar has a normal boiling point of at least 290° C.;, '(a) providing a first pyrolysis tar, wherein,'}{'sub': 'T', '(b) isolating a sample from the first pyrolysis tar and measuring a reactivity Rof the sample;'}{'sub': T', 'Ref, 'claim-text': [{'sub': T', 'Ref, '(i) when Ris less than or equal to a predetermined reference reactivity R, carrying out the hydroprocessing of step (d); or'}, {'sub': T', 'Ref, 'claim-text': [{'sub': HS', 'HS', 'HS', 'HS', 'HS, '(A) heating the first pyrolysis tar to achieve a temperature Tand maintaining the first pyrolysis tar at a temperature in a range of from Tto 360° C. for a time of time tto produce a pyrolysis tar composition, wherein Tis in the range of from 150° C. to 350° C. and tis ≥1 minute,'}, {'sub': 'T', '(B) isolating a sample from the pyrolysis tar composition and measuring the reactivity Rof the pyrolysis tar composition sample, and'}, '(C) repeating step (c); and, '(ii) when Ris greater than a predetermined reference reactivity R,'}], '(c) comparing Rto a predetermined reference reactivity R, wherein,'}(d) hydroprocessing at least a portion of the pyrolysis tar composition to produce a hydroprocessor effluent comprising hydroprocessed pyrolysis tar.2. (canceled)3. The process of claim 1 , wherein (i) Rand Rare determined by a Bromine Number measurement and expressed in BN units claim 1 , (ii) Ris ≤20 BN claim 1 , and ( ...

Separation vessel or part thereof, and process relating thereto

One exemplary embodiment can be a stack for a separation vessel adapted to receive a fluid having one or more phases. The stack may include one or more walls surrounding a void, a packed bed positioned within the void, and a distributor positioned above the packed bed. Generally, the stack has a height greater than its width. Usually, the separation vessel further includes a base having a length greater than its height, and the height of the stack is orientated substantially perpendicular to the length of the base.

process for hydrocarbon reform

resumo patente de invenção: "processo para a reforma de hidrocarbonetos". a presente invenção refere-se a um processo para a produção de gás de síntese mediante o uso de reforma autotérmica em que o gás de cauda da síntese de fischer-tropsh a jusante é hidrogenado e é adicionado então ao estágio de reforma autotérmica. 20118977v1 patent summary: "process for hydrocarbon reforming". The present invention relates to a process for producing synthesis gas using autothermal reforming wherein the downstream fischer-tropsh synthesis tail gas is hydrogenated and is then added to the autothermal reforming stage. 20118977v1

Naphthenic acid corrosion inhibitors for a refinery

Corrosion inhibitor compositions and methods for inhibiting corrosion on a metal surface exposed to a hydrocarbon fluid are provided. The corrosion inhibition compositions can include a corrosion inhibitor, such as 3-dimethylamino benzoic acid, 4-dimethylamino benzoic acid, or 2,5-dihydroxyterephthalic acid. The corrosion inhibitor composition can further comprise dimethyl sulfoxide, and heavy aromatic naphtha. The corrosion inhibitor composition can be phosphate-free and can inhibit naphthenic acid corrosion. In the methods, a corrosion inhibitor composition is added to the hydrocarbon fluid exposed to the metal surface to prevent or inhibit corrosion on the metal surface, including naphthenic acid corrosion.

Naphthenic acid corrosion inhibitors for a refinery

Corrosion inhibitor compositions and methods for inhibiting corrosion on a metal surface exposed to a hydrocarbon fluid are provided. The corrosion inhibition compositions can include a corrosion inhibitor, such as 3-dimethylamino benzoic acid, 4-dimethylamino benzoic acid, or 2,5-dihydroxyterephthalic acid. The corrosion inhibitor composition can further comprise dimethyl sulfoxide, and heavy aromatic naphtha. The corrosion inhibitor composition can be phosphate-free and can inhibit naphthenic acid corrosion. In the methods, a corrosion inhibitor composition is added to the hydrocarbon fluid exposed to the metal surface to prevent or inhibit corrosion on the metal surface, including naphthenic acid corrosion.

Polymeric Pour Point Depressants For Waxy Crude Oils

This invention relates a wax inhibitor for hydrocarbon oils comprising an esterified copolymer having repeating structural units derived from an esterified ethylenically unsaturated dicarboxylic acid and α-olefins having at least 18 carbon atoms, whereof at least 3 mol-% of the α-olefins have 30 or more carbon atoms, and wherein the ethylenically unsaturated dicarboxylic acid has been esterified with a mixture of alcohols comprisingi) 70 to 97 mol-% of a saturated fatty alcohol having 18 to 24 carbon atoms andii) 3 to 30 mol-% of an unsaturated alcohol having 16 to 24 carbon atoms.

Method of removal of carbonyl compounds along with acid gases from cracked gas in ethylene process

A method for inhibiting and dissolving polymeric deposits on the internal surfaces of a caustic wash unit system in a hydrocarbon cracking process wherein said deposits result from polymerization of at least one component contained within a feed stream of said caustic wash unit system. The method comprises the step of introducing into said stream an effective amount of a compound selected from a group consisting of alkali metal salts of oxo acids of sulfur, alkali metal salts of acids of lactam, alkali metal salts of acids of sultam, alkali metal salts of amino acids, alkaline earth metal salts of acids of sultam, alkaline earth metal salts of amino acids, lactam, sultam, amino acids, and combinations thereof, wherein said effective amount inhibits polymerization and dissolves said deposits.

Upgraded ebullated bed reactor with no recycle buildup of asphaltenes in vacuum bottoms

An ebullated bed hydroprocessing system is upgraded using a dual catalyst system that includes a heterogeneous catalyst and dispersed metal sulfide particles, which permits recycling of vacuum bottoms without recycle buildup of asphaltenes. The dual catalyst system more effectively converts asphaltenes in the ebullated bed reactor and increases asphaltene conversion by an amount that at least offsets higher asphaltene concentration resulting from recycling of vacuum bottoms. In this way, there is no recycle buildup of asphaltenes in upgraded ebullated bed reactor notwithstanding recycling of vacuum bottoms. In addition, residual dispersed metal sulfide catalyst particles in the vacuum bottoms can maintain or increase the concentration of the dispersed metal sulfide catalyst in the ebullated bed reactor.

Hydrohalogenation of vinyl terminated polymers and their functionalized derivatives for fouling mitigation in hydrocarbon refining processes

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.

Amination of polymers terminated with aldehyde group and their functionalized derivatives for fouling mitigation in hydrocarbon refining processes

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

Hydrohalogenation of vinyl terminated polymers and their functionalized derivatives for fouling mitigation in hydrocarbon refining processes

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.

Hydrohalogenation of vinyl terminated polymers and their functionalized derivatives for fouling mitigation in hydrocarbon refining processes

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.

Hydrohalogenation of vinyl terminated polymers and their functionalized derivatives for fouling mitigation in hydrocarbon refining processes

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.

Process using polypropylene or poly (ethylene co propylene) succinimide as antifouling additive in petroleum refinery processes

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.

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

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.

Method of dispersing hydrocarbon foulants in hydrocarbon processing fluids

A method of dispersing, dissolving, or reducing the viscosity of hydrocarbon foulaπts including heavy oil, tars, asphaltenes, polynuclear aromatic hydrocarbons, coke, polymers, light oil, oxidized hydrocarbon and thermal decomposition products, and the like in fluids in contact with hydrocarbon processing equipment (1-7, Figure 1) comprising contacting the foulant with an effective amount of a halogen-free organic solvent having a density greater than water at the processing temperature.

Method, apparatus and chemical products for treating petroleum equipment

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.

Addition of high molecular weight naphthenic tetra-acids to crude oils to reduce whole crude oil fouling

High molecular weight naphthenic tetra-acids are added to a base crude oil to prevent and/or reduce fouling of crude oil refinery equipment. The method includes adding an effective amount of a high molecular weight naphthenic tetra-acid to the base crude oil to form a crude oil mixture and feeding the crude oil mixture to a crude oil refinery component. Particularly, the high molecular weight naphthenic tetra-acids include ARN acids.

Method of dispersing hydrocarbon foulants in hydrocarbon processing fluids

A method of dispersing, dissolving, or reducing the viscosity of hydrocarbon foulants including heavy oil, tars, asphaltenes, polynuclear aromatic hydrocarbons, coke, polymers, light oil, oxidized hydrocarbon and thermal decomposition products, and the like in fluids in contact with hydrocarbon processing equipment comprising contacting the foulant with an effective amount of a halogen-free organic solvent having a density greater than water at the processing temperature.

使烃加工液体中的烃类污物分散的方法

一种使与烃加工装置接触的液体中的烃类污物分散、溶解或降低其粘度的方法，所述的烃类污物包括重油、焦油、沥青质、多核芳香烃、焦炭、聚合物、轻油、氧化烃和热解产物和类似物，该方法包括使污物与有效量的不含卤素的有机溶剂接触，所述的有机溶剂在加工温度下密度大于水。

Method, apparatus and chemical products for treating petroleum equipment

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.

Method and apparatus for treating petroleum equipment

Integrated hydrotreating and steam pyrolysis process for direct processing of a crude oil

An integrated hydrotreating and steam pyrolysis process for the direct processing of a crude oil is provided to produce olefinic and aromatic petrochemicals. Crude oil and hydrogen are charged to a hydroprocessing zone operating under conditions effective to produce a hydroprocessed effluent reduced having a reduced content of contaminants, an increased paraffinicity, reduced Bureau of Mines Correlation Index, and an increased American Petroleum Institute gravity. Hydroprocessed effluent is thermally cracked in the presence of steam to produce a mixed product stream, which is separated. Hydrogen from the mixed product stream is purified and recycled to the hydroprocessing zone, and olefins and aromatics are recovered from the separated mixed product stream.

减少催化裂化沉降器结焦的防焦蒸汽环管

本发明涉及一种减少催化裂化沉降器结焦的防焦蒸汽环管，主要解决现有技术中催化裂化沉降器结焦严重、停车事故较多的问题。本发明通过采用一种减少催化裂化沉降器结焦的防焦蒸汽环管，所述防焦蒸汽环管(4)与蒸汽引入管线(6)相连，防焦蒸汽环管(4)上开有多个孔，开孔率为0.01～0.1，所述孔上连接蒸汽喷头(5)，所述孔直径与防焦蒸汽环管(4)的管内径之比为0.1～0.6，防焦蒸汽环管(4)直径与催化裂化沉降器直径之比为0.2～0.6，蒸汽喷头(5)的轴线与沉降器轴线的夹角为0～90°的技术方案较好地解决了上述问题，可用于催化裂化沉降器结焦的防焦中。

A New Additive for Inhibiting Acid Corrosion and Method of Using the New Additive

본 발명은 탄화수소 유체 프로세싱 유니트에서의 부식억제에 관한 것이다. 본 발명은 모노, 디 혹은 폴리 히드록시 그룹을 갖는 중합체 화합물, 바람직하게는 히드록시-말단 중합체 화합물, 보다 바람직하게는 히드록시 말단 폴리이소부틸렌 혹은 폴리부텐을 포함하는 중합체 화합물 및 포스포러스 펜타술파이드의 반응으로 얻어지는 중합 티오포스페이트 에스테르를 포함하는 산 부식을 억제하는 새로운 첨가제를 포함한다. 상기 중합 티오포스페이트 에스테르는 에틸렌 옥사이드, 부틸렌 옥사이드 혹은 프로필렌 옥사이드 혹은 이러한 다른 옥사이드로 구성되는 그룹으로 부터 선택되는 어떠한 옥사이드, 바람직하게는 에틸렌 옥사이드와 추가로 반응하여 티오포스페이트 에스테르의 에틸렌 옥사이드 유도체를 형성한다. 본 발명은 증류 유니트, 증류 컬럼, 트레이, 패킹 및 펌프 어라운드 파이핑의 금속 표면의 산 부식 억제 효과에 유용하다. The present invention relates to corrosion inhibition in hydrocarbon fluid processing units. The present invention relates to polymer compounds having mono, di or poly hydroxy groups, preferably hydroxy-terminated polymer compounds, more preferably polymer compounds comprising hydroxy terminated polyisobutylene or polybutene and phosphorus pentasul New additives that inhibit acid corrosion, including polymeric thiophosphate esters obtained by the reaction of the pyodes. The polymerized thiophosphate ester is further reacted with any oxide selected from the group consisting of ethylene oxide, butylene oxide or propylene oxide or such other oxides, preferably ethylene oxide to form ethylene oxide derivatives of thiophosphate esters. . The present invention is useful for acid corrosion inhibiting effects of metal surfaces of distillation units, distillation columns, trays, packings and pump around piping.

将高分子量环烷四酸加入原油中以降低全原油积垢的方法

将高分子量环烷四酸加入基础原油中以防止和/或降低原油精炼设备积垢。该方法包括将有效量的高分子量环烷四酸加入基础原油中以形成原油混合物，并将原油混合物供入原油精炼组件中。特别地，高分子量环烷四酸包括ARN酸。

Method for preventing fouling in chemical equipment and fouling inhibitor

Disclosed is a method for preventing fouling in chemical equipment by adding a fouling inhibitor, which includes a polyoxyalkylene polymer represented by formula (1) or (13) having a number-average molecular weight of no more than 30,000 g/mol, to the components in the chemical equipment. [A represents a group obtained by polymerizing a C 2-20 olefin; R 1 , R 2 , R 101 , and R 102 represent a hydrogen atom or a C 1-18 alkyl group; X 1 and X 2 are represented by formula (2) or formula (4); E, E 101 , and E 102 represent an oxygen atom or a sulfur atom; X 3 , X 7 , and X 8 represent a polyalkylene glycol group or a group represented by formula (3); R 3 represents a hydrocarbon group; G represents -OX 4 or -NX 5 X 6 (X 4 -X 6 represent a polyalkylene glycol group); m represents an integer in the range of 1 to 10; A 101 represents a group obtained by polymerizing a C 2-20 olefin; one of X 101 and X 102 represents a hydrogen atom or a group represented by formula (14) or formula (15), and the other represents a group represented by formula (16); R 104 represents a hydrogen atom, a hydrocarbon group, or an acyl group; R 105 and R 106 represent a hydrocarbon group; and X 104 represents a polyalkylene glycol group]

Method for preventing fouling in chemical equipment and fouling inhibitor

본 발명에서는, 화학식 (1) 또는 화학식 (13)으로 표시되는 Mn 30000 이하의 폴리옥시알킬렌계 중합체를 포함하는 파울링 방지제를 화학 장치 내의 성분에 첨가하는 것을 포함하는 화학 장치의 파울링 방지 방법이 제공된다[A: 탄소수 2∼20의 올레핀이 중합된 기; R 1 , R 2 , R 101 , R 102 : H, 탄소수 1∼18의 알킬기; X 1 및 X 2 : 화학식 (2), 화학식 (4); E, E 101 , E 102 : O, S; X 3 , X 7 , X 8 : 폴리알킬렌 글리콜기, 화학식 (3); R 3 : 탄화수소기; G: -OX 4 , -NX 5 X 6 (X 4 ∼X 6 은 폴리알킬렌 글리콜기); m: 1∼10; A 101 : 탄소수 2∼20의 올레핀이 중합된 기; X 101 , X 102 : 한쪽이 수소 원자, 화학식 (14) 또는 화학식 (15), 다른 쪽이 화학식 (16); R 104 : H, 탄화수소기, 아실기; R 105 및 R 106 : 탄화수소기; X 104 : 폴리알킬렌 글리콜기]. In the present invention, a method for preventing fouling of a chemical apparatus comprising adding an antifouling agent comprising a polyoxyalkylene-based polymer of Mn 30000 or less represented by the formula (1) or formula (13) to a component in the chemical apparatus. [A: group in which olefins having 2 to 20 carbon atoms are polymerized; R 1 , R 2 , R 101 , R 102 : H, an alkyl group having 1 to 18 carbon atoms; X 1 and X 2 : formula (2), formula (4); E, E 101 , E 102 : O, S; X 3 , X 7 , X 8 : polyalkylene glycol group, formula (3); R 3 : hydrocarbon group; G: -OX 4 , -NX 5 X 6 (X 4 to X 6 are polyalkylene glycol groups); m: 1 to 10; A 101 : group in which an olefin having 2 to 20 carbon atoms is polymerized; X 101 , X 102 : one side a hydrogen atom, formula (14) or formula (15), and the other formula (16); R 104 : H, hydrocarbon group, acyl group; R 105 and R 106 : hydrocarbon group; X 104 : polyalkylene glycol group.

가솔린 분별 내의 침전물 경감, 급냉수 시스템 및 생성물 회수 섹션

침전물 형성의 경감, 기존의 침전물들의 세척 및/또는 침전물 형성률의 감소에 대하여 유용한 용매들의 혼합물 또는 용매를 선택하는 방법이 개시되었다. 침전물들이 형성되는 비율의 감소 및/또는 침전물들이 제거되는 비율의 증가는 프로세스 경제 조건을 극적으로 증가시킬 수 있다(예를 들어, 침전물 형성의 결과로서 고장시간의 감소). 일 측면에서, 여기에 개시된 실시예들은 탄화수소 스트림 내의 풀라들을 분산하는 프로세스와 관련 있는 것으로, 탄화수소 스트림 내의 풀라들의 성질을 결정하는 단계; 상기 결정된 성질을 기반으로 상기 풀라들을 분산하기에 적절한 용매들의 혼합물 또는 용매를 선택하는 단계; 및 상기 풀라들을 상기 선택된 용매 또는 용매들의 혼합물과 접촉시키는 단계를 포함한다.

Retractable nozzle for refractory-lined equipment

A refractory-lined equipment includes a vessel defining an interior at least partially lined with a refractory material, and a nozzle assembly coupled to the vessel and extending into the interior. The nozzle assembly includes an outer sleeve fixed to the sidewall and extending through an aperture defined in the sidewall, the outer sleeve defining a central passageway, and a nozzle cartridge assembly positionable within the central passageway and including an inner sleeve, a refractory lining disposed about the inner sleeve, and a nozzle positioned within the inner sleeve. The nozzle cartridge assembly is removably coupled to the outer sleeve external to the vessel.

Retractable nozzle for refractory-lined equipment

A refractory-lined equipment includes a vessel defining an interior at least partially lined with a refractory material, and a nozzle assembly coupled to the vessel and extending into the interior. The nozzle assembly includes an outer sleeve fixed to the sidewall and extending through an aperture defined in the sidewall, the outer sleeve defining a central passageway, and a nozzle cartridge assembly positionable within the central passageway and including an inner sleeve, a refractory lining disposed about the inner sleeve, and a nozzle positioned within the inner sleeve. The nozzle cartridge assembly is removably coupled to the outer sleeve external to the vessel.

Reducing pressure drop buildup in bio-oil hydroprocessing reactors

A method is provided involving reducing a pressure drop across a hydroprocessing reactor having a reactor feed and producing a hydroprocessing product, where the reactor feed includes a bio-oil feed and a hydrocarbon diluent; and the step of reducing the pressure drop comprises stopping or substantially reducing the bio-oil feed supplied to the reactor and supplying the hydrocarbon diluent to the reactor with a mass flux of at least about 1,000 lb/hr/ft 2 .

Reducing pressure drop buildup in bio-oil hydroprocessing reactors

A method is provided involving reducing a pressure drop across a hydroprocessing reactor having a reactor feed and producing a hydroprocessing product, where the reactor feed includes a bio-oil feed and a hydrocarbon diluent; and the step of reducing the pressure drop comprises stopping or substantially reducing the bio-oil feed supplied to the reactor and supplying the hydrocarbon diluent to the reactor with a mass flux of at least about 1,000 lb/hr/ft 2 .

원유 장치 내의 부식을 감소시키는 방법

부식 및 부식에 따른 부산물 퇴적의 감소를 위한 원유 장치 내의 시스템 파라미터들을 최적화하는 방법에 대하여 개시한다. 상기의 방법은 상기 시스템 파라미터들과 연관된 특성을 측정 또는 예측하는 단계 및 상기 시스템 파라미터들을 최적화하기 위하여 케미컬 프로그램을 조절함으로써 상기의 특성을 분석하는 자동화된 컨트롤러를 사용하는 단계를 포함한다. 상기의 시스템 파라미터들의 조절은 공정 스트림 내의 유체의 부식성을 감소시키거나 및/또는 잠재적으로 부식성 물질로부터 시스템을 보호함으로써 원유 장치 내의 부식을 효율적으로 컨트롤한다. 시스템 파라미터 센싱 프로브(sensing probe)들은 원유 장치 내에서 상기 시스템 파라미터들의 정확한 모니터링을 위하여 공정 스트림 내에 하나 또는 그 이상의 구역에 배치된다.

用于直接加工原油的整合的加氢处理和水蒸气热解方法

本发明提供一种用于直接加工原油的整合的加氢处理和水蒸气热解方法以便生产烯属和芳香族石油化学产品。将原油和氢装料至在有效于产生加氢加工的流出物的条件下操作的加氢加工区，所述加氢加工的流出物具有降低的污染物含量、增加的链烷烃含量、降低的美国矿务局关联指数以及增加的美国石油学会比重。加氢加工的流出物在存在水蒸气的情况下热裂解以产生混合的产物流，将所述产物流分离。将来自所述混合产物流的氢进行纯化并且再循环至所述加氢加工区，并且从所述分离的混合产物流回收烯烃和芳香族化合物。

Additives for reducing coking of furnace tubes

Fouling of hot furnace surfaces in selected refinery processes can be stopped or at least mitigated using an antifouling agent. The antifouling agents include sulfurized oil and may include other components selected from the group consisting of magnesium and aluminum overbases, a-olefin copolymers, and combinations thereof. It is emphasized that this abstract is provided to comply with the rules requiring an abstract which will allow a searcher or other reader to quickly ascertain the subject matter of the technical disclosure. It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims. 37 CFR 1.72(b)

REDUCTION OF DEPOSITS WHEN PETROL FACTIONATION, IN WATER COOLING SYSTEM AND PRODUCT REMOVAL SECTION

1. Способ диспергирования загрязняющих примесей в потоке углеводородов, причем способ включает стадии, на которых:определяют природу загрязняющих примесей в потоке углеводородов;выбирают растворитель или смесь растворителей, пригодные для диспергирования загрязняющих примесей, на основе определения их природы; иобеспечивают контактирование загрязняющих примесей с выбранными растворителем или смесью растворителей.2. Способ по п.1, в котором стадия, на которой определяют природу загрязняющих примесей, включает по меньшей мере одну из стадий, на которых:анализируют отложение, образовавшееся в результате обработки потока сырьевых углеводородов, для выявления по меньшей мере одного входного параметра для модели, используемой для выбора смеси; ианализируют поток углеводородов для установления по меньшей мере одного входного параметра для термодинамической модели, применяемой для выбора смеси;причем по меньшей мере один входной параметр включает по меньшей мере одно из:средней молекулярной массы загрязняющей примеси;плотности в градусах API;измеренной степени осаждения загрязняющей примеси;атомного отношения водорода к углероду в загрязняющей примеси;концентрации загрязняющей примеси в потоке углеводородов;концентрации осадочного материала (прогнозированного значения в испытании горячим фильтрованием фирмы Shell, которое используют для прогноза максимального содержания загрязняющих примесей) в сырьевом потоке.3. Способ по п.2, дополнительно включающий стадии, на которых:оценивают по меньшей мере одно свойство загрязняющей примеси на основе определения ее природы;причем по меньшей мере одно свойство РОССИЙСКАЯ ФЕДЕРАЦИЯ (19) RU (11) (13) 2012 110 827 A (51) МПК C10G 75/04 (2006.01) G05D 11/00 (2006.01) ФЕДЕРАЛЬНАЯ СЛУЖБА ПО ИНТЕЛЛЕКТУАЛЬНОЙ СОБСТВЕННОСТИ (12) ЗАЯВКА НА ИЗОБРЕТЕНИЕ (21)(22) Заявка: 2012110827/04, 30.03.2011 (71) Заявитель(и): ЛАММУС ТЕКНОЛОДЖИ ИНК. (US) Приоритет(ы): (30) Конвенционный приоритет: 09.04.2010 US 12/757,384 (85) Дата начала рассмотрения заявки ...

Integrated solvent deasphalting, hydrotreating and steam pyrolysis process for direct processing of a crude oil

올레핀 및 방향족 물질을 포함하는 석유화학제품을 제조하기 위한 원유 공급원료의 직접 가공처리를 허용하는 용매 탈아스팔트화 구역 및 수소처리 구역과 통합된 스팀 열분해 구역에 관한 공정이 제공된다. 올레핀 및 방향족 석유화학제품을 제조하기 위한 원유의 직접 가공처리를 위한 통합된 용매 탈아스팔트화, 수소처리 및 스팀 열분해 공정은 원유를 탈아스팔트화 및 탈금속화 오일 스트림 및 하부 아스팔트 상을 제조하기 위한 유효량의 용매와 용매 탈아스팔트화 구역으로 충전하는 단계; 탈아스팔트화 및 탈금속화 오일 스트림 및 수소를 오염물질 함량이 감소하고, 파라핀화도가 증가하고, 광산국 상관 지수가 감소하고, 미국 석유 협회 비중이 증가한 수소화 공정처리된 유출물을 제조하기에 효과적인 조건 하에 조작되는 수소화 공정 구역으로 충전하는 단계; 수소화 공정처리된 유출물을 스팀의 존재 하에 열 크래킹하여 혼합된 생성물 스트림을 제조하는 단계; 혼합된 생성물 스트림을 분리하는 단계; 혼합된 생성물 스트림으로부터 수소를 정제하고 이를 수소화 공정 구역으로 재순환시키는 단계; 분리된 혼합된 생성물 스트림으로부터 올레핀 및 방향족 물질을 회수하는 단계; 및 분리된 혼합된 생성물 스트림으로부터 열분해 연료 오일을 회수하는 단계를 포함한다. A process is provided for a steam pyrolysis zone integrated with a solvent deasphalting zone and a hydrotreating zone that allows the direct processing of crude oil feedstock for the production of petrochemicals comprising olefins and aromatics. Integrated solvent deasphalting, hydrotreating and steam pyrolysis processes for the direct processing of crude oils for the production of olefins and aromatic petrochemicals for Filling with an effective amount of solvent and a solvent deasphalting zone; Deasphalted and demetallized oil streams and hydrogen are effective for producing hydrogenated process effluents with reduced pollutant content, increased paraffinization, reduced mining country correlation index, and increased US Petroleum Association share. Charging to a hydrogenation process zone operated under conditions; Thermal cracking the hydroprocessed effluent in the presence of steam to produce a mixed product stream; Separating the mixed product stream; Purifying hydrogen from the mixed product stream and recycling it to the hydrogenation process zone; Recovering olefins and aromatics from the separated mixed product stream; And recovering the pyrolysis fuel oil from the separated mixed product stream.