ОТВОД АЗОТА ИЗ КОНДЕНСИРОВАННОГО ПРИРОДНОГО ГАЗА

Изобретение может быть использовано в технологии обработки природного газа. Способ отвода азота включает введение конденсированного природного газа в первом положении дистилляционной колонны, отбор обогащенного азотом потока пара из головной части дистилляционной колонны и отбор очищенного потока сжиженного природного газа из нижней части колонны. Поток холодного орошения вводят в дистилляционную колонну во втором положении, находящемся выше первого положения. Способ также включает либо охлаждение очищенного потока сжиженного природного газа, или охлаждение потока конденсированного природного газа, либо охлаждение как очищенного потока сжиженного природного газа, так и потока конденсированного природного газа. Технический результат: удаление азота с минимальными потерями метана и обеспечение принудительного охлаждения сжиженного природного газа. 5 н. и 28 з.п. ф-лы, 8 ил.

СПОСОБ ОБРАБОТКИ ПИТАЮЩЕГО ГАЗОВОГО ПОТОКА И УСТАНОВКА ДЛЯ ЕГО ОСУЩЕСТВЛЕНИЯ

Изобретение касается способа обработки питающего газа, в котором обеспечивают питающий газовый поток и направляют питающий газовый поток в экстракционную установку для извлечения жидкостей природного газа; в экстракционной установке охлаждают и предпочтительно по меньшей мере частично сжижают питающий газовый поток, расширяют в средстве расширения и разделяют в сепарационной колонне по меньшей мере один поток, полученный из охлажденного питающего газового потока, и после разделения извлекают обработанный газовый поток и поток жидкостей природного газа; сжимают обработанный газовый поток в по меньшей мере одном компрессоре установки сжатия для получения сжатого обработанного газового потока; в фракционной установке производят разделение потока жидкостей природного газа на множество углеводородных фракций. И из сжатого обработанного газового потока отбирают поток рецикла; и повторно вводят поток рецикла без его охлаждения в питающий газовый поток выше по ходу потока от экстракционной установки ...

СПОСОБ ДЕГИДРАТАЦИИ УГЛЕВОДОРОДНОГО ГАЗА

Изобретение относится к способу дегидратации газа с помощью жидкого влагопоглотителя с использованием открытого контура потока углеводородов. Способ дегидратации влажного углеводородного газа, в котором осуществляют следующие стадии: a) обеспечение неочищенного углеводородного газа, содержащего метан, по меньшей мере углеводороды C4+ и воду, и b) трехфазное разделение указанного неочищенного углеводородного газа, с получением влажного углеводородного газа, жидких углеводородных конденсатов и жидкого водного потока, и отправка указанного влажного углеводородного газа на стадию c), c) контактирование указанного влажного углеводородного газа с регенерированным жидким влагопоглотителем, полученным на стадии e), чтобы получить дегидратированный газ и жидкий влагопоглотитель, наполненный водой, d) отделение фракции, богатой углеводородными соединениями C4-C10, содержащейся в дегидратированном газе, чтобы получить остаточный газ, обедненный углеводородами C4+, и поток пара, богатого углеводородами ...

СПОСОБ ПОЛУЧЕНИЯ ГРАНУЛ ГАЗОВОГО ГИДРАТА

Настоящее изобретение относится к способу получения гранул газового гидрата. Способ получения гранул газового гидрата включает образование газового гидрата реакцией сырого газа и сырой воды при заданных условиях температуры и давления, дегидратирование образовавшегося газового гидрата дегидратирующим устройством, затем формирование газового гидрата в гранулы посредством устройства для гранулирования, имеющего функции дегидратации, и охлаждение газового гидрата в виде гранул. Технический результат - подавление расщепления газового гидрата в процессе сброса давления, получение гранул с высокой концентрацией газового гидрата, снижение расщепления газового гидрата в процессе хранения, а также обеспечение процесса производства гранул газового гидрата, не вызывающего блокирования в устройстве сброса давления или окружающих его трубах. 3 н.п. ф-лы, 9 ил.

СПОСОБ УДАЛЕНИЯ ГАЗОВЫХ КОМПОНЕНТОВ КИСЛОТНОГО ХАРАКТЕРА ИЗ ГАЗОВ

Изобретение относится к способу удаления из газов газовых компонентов кислотного характера из группы, состоящей из двуокиси углерода, сероводорода, сероокиси углерода, сероуглерода и меркаптанов. Сущность изобретения: неочищенный богатый газовыми компонентами кислотного характера газ вводится в контакт с абсорбентом на стадии абсорбции, при этом получают очищенный газ, обедненный газовыми компонентами кислотного характера, и абсорбент, насыщенный газовыми компонентами кислотного характера, причем в качестве абсорбента используется смесь, содержащую а) от 5 до 30 мас.% незамещенного пиперазина в качестве компонента А; б) от 2 до 45 мас.% многоатомного спирта, не содержащего аминогруппы в качестве компонента Б; в) от 0 до 60 мас.% алифатического алканоламина в качестве компонента В; г) от 30 до 70 мас.% воды в качестве компонента Г; д) от 0 до 35 мас.% карбоната калия в качестве компонента Д, причем сумма компонентов А, Б, В, Г и Д составляет 100 мас.%. Предлагаемый абсорбент помимо высокой ...

СПОСОБ ДЕСУЛЬФУРИЗАЦИИ УГЛЕВОДОРОДОВ И СПОСОБ РИФОРМИНГА УГЛЕВОДОРОДНОГО СЫРЬЯ

Группа изобретений относится к десульфуризации углеводородов. Способ включает стадии: (i) пропускание смеси углеводорода и водорода через катализатор десульфуризации с превращением сероорганических соединений, присутствующих в указанном углеводороде, в сульфид водорода, (ii) пропускание полученной смеси через сорбент сульфида водорода, содержащий оксид цинка, со снижением содержания сульфида водорода в смеси, и (iii) пропускание газовой смеси, обедненной сульфидом водорода, через дополнительный десульфуризующий материал. Дополнительный десульфуризующий материал содержит формованную смесь одного или более соединений никеля в виде частиц, материал носителя, содержащий оксид цинка в виде частиц, и, необязательно, одно или более соединений промотирующих металлов в виде частиц, выбранных из железа, кобальта, меди и благородных металлов. Причем указанный десульфуризующий материал содержит 0,3-20 мас.% никеля и 0-10 мас.% промотирующего металла. Предложен также способ риформинга углеводородного ...

СПОСОБ ПРЕДОТВРАЩЕНИЯ ОБРАЗОВАНИЯ ГИДРАТОВ В ТЕКУЧИХ СРЕДАХ, СОДЕРЖАЩИХ ГАЗ ИЛИ ГАЗОВЫЙ КОНДЕНСАТ

Изобретение относится к способу предотвращения образования гидратов в текучих средах, содержащих газы или газовые конденсаты. Способ включает воздействие на указанные текучие среды электромагнитными волнами в пределах видимой и инфракрасной области спектра, заключенной в диапазоне λ от 500 нм или более до менее 1 мм (от более 300 ГГц до 600 ТГц или менее), для предотвращения образования кристаллических связей, ответственных за образование указанных гидратов. Эффективность способа основана на использовании электромагнитного излучения в пределах четко определенного диапазона частот без необходимости применения химических добавок. 2 н. и 8 з.п. ф-лы, 1 табл., 4 ил.

СПОСОБ ОЧИСТКИ СЖИЖЕННЫХ УГЛЕВОДОРОДОВ С ПРИМЕНЕНИЕМ СОЕДИНЕНИЙ 3-(ПИПЕРАЗИН-1-ИЛ)ПРОПАН-1, 2 ДИОЛА

Изобретение относится к способу очистки сжиженных углеводородов, таких как сжиженный нефтяной газ (LPG) или сжиженный природный газ (NGL). Способ обработки сжиженных углеводородов, содержащих кислые газы, для удаления упомянутых кислых газов при сведении к минимуму потери аминосоединений, включает этап контактирования упомянутых сжиженных углеводородов с абсорбирующим водным раствором первого аминосоединения, причем упомянутое первое аминосоединение имеет структуру:,в которой Rпредставляет собой водород, пропан-2,3-диол и их смеси, и Rпредставляет собой пропан-2,3-диол. Технический результат - сведение к минимуму потерь аминосоединений. 8 з.п. ф-лы, 1 ил.

РЕАКТОР ДЛЯ ПОЛУЧЕНИЯ УГЛЕРОДНОГО МАТЕРИАЛА КАТАЛИТИЧЕСКИМ ПИРОЛИЗОМ УГЛЕВОДОРОДСОДЕРЖАЩИХ ГАЗОВ

Изобретение может быть использовано для обезвреживания углеводородсодержащих газов. В корпус 1 засыпают слой катализатора. Реагентный газ, проходя через теплообменную рубашку 4, трубопровод 6 и коллектор 7, попадает через патрубки 8 в корпус реактора 1. Фильтруясь через слой катализатора 9, реагентный газ по трубопроводу 12 поступает в камеру сгорания по оси воздушного клапана 14 и воспламеняется запальником 13. После короткого промежутка времени камера пульсирующего горения, образованная камерой сгорания 2, резонансной трубой 3 и воздушным клапаном 14, выходит на устойчивый режим пульсирующего сжигания реагентного газа. Прогретый в рубашке 4 реагентный газ по трубопроводу 6, коллектору 7 и патрубкам 8 направляется на пиролиз в слой катализатора 9. В результате процесса пиролиза в корпусе 1 на катализаторе синтезируется углеродный материал и образуются газообразные горючие продукты, которые через трубопровод 12 вновь поступают в камеру сгорания 2, где утилизируются сжиганием. Изобретение ...

УСТАНОВКА ДЛЯ ПОДГОТОВКИ ПОПУТНОГО НЕФТЯНОГО ГАЗА

Настоящее изобретение относится к установке для подготовки попутного нефтяного газа, включающей конвертор и дефлегматор. При этом на линии подачи попутного нефтяного газа установлен сатуратор, оснащенный линиями ввода нагретой и вывода охлажденной воды и линией вывода газа сатурации, на которой после примыкания линии подачи водного конденсата расположены дефлегматор, рекуперационный теплообменник и конвертор, оснащенный линией вывода конвертированного газа, на которой после примыкания линии ввода воздуха расположен реактор селективного каталитического окисления водорода с линией вывода газопаровой смеси, на которой расположены рекуперационный теплообменник и дефлегматор, оснащенный линиями подачи охлаждающей/вывода нагретой воды, а также линиями вывода водного конденсата и подготовленного газа. Технический результат - исключение подачи тепла со стороны и снижение содержания водорода в подготовленном газе. 1 ил.

СПОСОБЫ ХОЛОДОСНАБЖЕНИЯ В УСТАНОВКАХ ДЛЯ ИЗВЛЕЧЕНИЯ ГАЗОКОНДЕНСАТНЫХ ЖИДКОСТЕЙ

Изобретение относится к извлечению газоконденсаторных жидкостей. Способ извлечения газоконденсатных жидкостей (NGL), включающий: введение подаваемого потока природного газа в основной теплообменник, в котором подаваемый поток охлаждается и частично конденсируется, введение частично конденсированного подаваемого потока в холодный газожидкостный сепаратор, в котором частично конденсированный подаваемый поток разделяется на жидкую фракцию и газообразную фракцию, введение жидкой фракции в разделительную или ректификационную колонну, разделение газообразной фракции на первую часть и вторую часть, охлаждение первой части газообразной фракции в верхнем теплообменнике путем косвенного теплообмена с потоком верхнего газообразного продукта, отводимым из верхней части разделительной или ректификационной колонны, и введение охлажденной и частично конденсированной первой части газообразной фракции в разделительную или ректификационную колонну в точке, расположенной выше точки введения жидкой фракции ...

СПОСОБ УДАЛЕНИЯ АЗОТА ИЗ ОБОГАЩЕННОЙ УГЛЕВОДОРОДОМ ФРАКЦИИ

Изобретение относится к способу получения сжиженного углеводородного газа с низким содержанием азота. Способ получения сжиженной обогащенной углеводородом фракции (фракции продукта) с содержанием азота ≤ 1 мол.% осуществляют следующим образом. Обогащенную углеводородом фракцию сжижают и переохлаждают с помощью холодильного контура, а затем подвергают ректификационному удалению азота. Способ отличается тем, что: а) сжиженную и переохлажденную обогащенную углеводородом фракцию (2) расширяют (V1) и подают в колонну (Т1) отгонки азота, б) фракцию (4) продукта отводят из ее нижней части, в) обогащенную азотом фракцию (5) отводят из ее верхней части, сжимают (С1), сжижают и переохлаждают (Е1-Е3) с помощью холодильного контура (К), расширяют (V2) и подают в колонну (Т2) азота высокого давления, г) часть потока обогащенной азотом фракции из колонны (Т2) азота высокого давления, который был охлажден с помощью холодильного контура (K), подают в качестве ребойлерного потока (9), д) обедненную азотом ...

КОМПОЗИЦИОННОЕ ИЗДЕЛИЕ

Изобретение относится к композиционному изделию, способу его получения и применения, в частности для разделения газов. Композиционное изделие, содержащее на пористой подложке и в пустотах подложки, которая включает волокна, предпочтительно из неэлектропроводного материала, пористый слой 1, состоящий из частиц оксида, связанных между собой и частично с подложкой, которые включают по меньшей мере один оксид, выбранный из оксидов элементов Al, Zr, Ti и Si, предпочтительно выбранный из Al2O3, ZrO2, TiO2 и SiO2, и содержащее, по меньшей мере с одной стороны, дополнительный пористый слой 2, включающий частицы оксида, связанные между собой и частично со слоем 1, которые включают по меньшей мере один оксид, выбранный из оксидов элементов Al, Zr, Ti и Si, предпочтительно выбранный из Al2O3, ZrO2, TiO2 и SiO2, где частицы оксида, присутствующие в слое 1, имеют медианный размер частиц d50 от 0,5 до 4 мкм, а медианный размер частиц d50 частиц оксида в слое 2, составляет от 0,015 до 0,15 мкм, предпочтительно ...

СПОСОБ ТРАНСПОРТИРОВКИ ОХЛАЖДЕННОГО ПРИРОДНОГО ГАЗА (ВАРИАНТЫ)

Изобретение относится к хранению природного газа под давлением в контейнере и последующей транспортировке находящегося под давлением контейнера, заполненного природным газом или смесью, подобной природному газу и содержащей метан, а также добавку, такую как углеводородные соединения С2, С3, С4, С5 или С6+, в том числе все насыщенные и ненасыщенные углеводороды, или диоксид углерода. Смесь охлаждена до температуры ниже температуры окружающей среды. Изобретение также относится к аналогичной смеси, полученной путем удаления метана или бедного газа из более богатой смеси природного газа. Техническим результатом изобретения является повышение эффективности хранения и транспортировки газа. 6 н. и 10 з.п. ф-лы, 13 ил.

СПОСОБ ОБРАБОТКИ СЖИЖЕННЫХ УГЛЕВОДОРОДОВ С ИСПОЛЬЗОВАНИЕМ 3-(АМИНО)ПРОПАН-1,2-ДИОЛЬНЫХ СОЕДИНЕНИЙ

Изобретение относится к способу обработки потоков сжиженных углеводородов (NGL или LPG). Способ обработки сжиженных углеводородов, содержащих кислые газы, для удаления указанных кислых газов при минимизации потерь соединений аминов, содержит стадию приведения в контакт указанных сжиженных углеводородов с поглощающим водным раствором первого аминосоединения, причем указанное первое аминосоединение имеет структуру,где Rпредставляет собой пропан-2,3-диол; Rпредставляет собой водород, метил, этил, 2-гидроксиэтил или пропан-2,3-диол; и Rпредставляет собой водород, метил, этил, 2-гидроксиэтил или пропан-2,3-диол. Технический результат – минимизация потерь аминов. 8 з.п. ф-лы, 1 ил.

ВОДНАЯ АЛКАНОЛАМИНОВАЯ АБСОРБИРУЮЩАЯ КОМПОЗИЦИЯ, СОДЕРЖАЩАЯ ПИПЕРАЗИН ДЛЯ УЛУЧШЕННОГО УДАЛЕНИЯ СЕРОВОДОРОДА ИЗ ГАЗОВЫХ СМЕСЕЙ, И СПОСОБ ЕЕ ИСПОЛЬЗОВАНИЯ

Изобретение относится к водному раствору алканоламина для удаления сероводорода из газовых смесей, содержащих сероводород. Водный раствор алканоламина для удаления кислых газов, включающих в себя сероводород, из газовых смесей, содержащих сероводород, содержит:(i) от 20 до 50 массовых процентов 3-(диметиламин)-1,2-пропандиола или 3-(диэтиламин)-1,2-пропандиола, и (ii) от 2 до 10 массовых процентов пиперазина, при этом массовый процент берется в расчете на общую массу водного раствора алканоламина и при этом упомянутый водный раствор алканоламина не содержит ортофосфорную кислоту, фосфорную кислоту, соляную кислоту, серную кислоту, сернистую кислоту, азотную кислоту, пирофосфорную кислоту, теллуровую кислоту, уксусную кислоту, муравьиную кислоту, адипиновую кислоту, бензойную кислоту, н-бутановую кислоту, монохлоруксусную кислоту, лимонную кислоту, глутаровую кислоту, молочную кислоту, малоновую кислоту, щавелевую кислоту, о-фталевую кислоту, янтарную кислоту, о-толуиловую кислоту. Заявлен ...

Способ очистки природного газа от примесей диоксида углерода и метанола

Изобретение относится к способу очистки природного газа от примесей диоксида углерода и метанола, включающему абсорбционное извлечение из природного газа диоксида углерода и метанола водным раствором амина в абсорбере с последующей регенерацией насыщенного абсорбента в колонне регенерации амина с получением регенерированного абсорбента, кислой воды и кислого газа, характеризующемуся тем, что поток кислой воды из рефлюксной емкости колонны регенерации амина разделяют на две части. Первую часть отводят, а вторую возвращают в колонну регенерации амина в качестве орошения. Соотношение между первой частью и всем потоком кислой воды из рефлюксной емкости колонны регенерации амина в диапазоне от 0 до 100 % регулируют путем обеспечения такой концентрации метанола в регенерированном абсорбенте, поступающем в абсорбер в качестве орошения, при которой концентрация метанола в очищенном природном газе на выходе из абсорбера не превышает допустимой величины. Техническим результатом является очистка природного ...

СПОСОБ ПОЛУЧЕНИЯ КОНДЕНСАТА И ОСУШКИ ПРИРОДНОГО ГАЗА И ПРОТОЧНЫЙ РЕАКТОР ДЛЯ ЕГО ОСУЩЕСТВЛЕНИЯ

Изобретение относится к газовой промышленности и может использоваться для извлечения тяжелых углеводородов из природного газа и для его осушки при подготовке к транспортировке. Струю газовой смеси предварительно дросселируют с последующим облучением электромагнитной волной ультрафиолетового диапазона с длиной волны 130-200 нм. Для получения конденсата и осушки природного газа используют проточный реактор, корпус 12 которого представляет собой отрезок трубы. На входе в реактор размещено сопло 3, после которого располагаются эксимерные лампы 4 на основе ксенона. Технический результат: повышение эффективности выхода конденсата, снижение влажности, утилизация отделяемой влаги и снижение энергозатрат. 2 н.п. ф-лы, 4 ил.

СПОСОБ БЕЗОТХОДНОЙ ПОДГОТОВКИ СКВАЖИННОЙ ПРОДУКЦИИ (ВАРИАНТЫ)

Группа изобретений относится к способам подготовки газа путем низкотемпературной конденсации и может быть использована в газовой промышленности для промысловой подготовки скважинной продукции газоконденсатных месторождений. Согласно первому варианту предложенного способа сырой газ сепарируют на первой ступени с получением газа, водного и углеводородного конденсатов, последний редуцируют и стабилизируют совместно с конденсатом второй ступени с получением первого газа стабилизации и остатка. Газ первой ступени редуцируют и в смеси с первым газом стабилизации сепарируют на второй ступени путем охлаждения в условиях дефлегмации с получением конденсата и газа, который редуцируют, смешивают со вторым газом стабилизации и сепарируют на третьей ступени с получением конденсата и газа, который нагревают и выводят в качестве товарного. Остаток стабилизации редуцируют и стабилизируют совместно с конденсатом третьей ступени с получением товарного конденсата и второго газа стабилизации. Согласно второму ...

СПОСОБ ИЗВЛЕЧЕНИЯ КОМПОНЕНТОВ ИЗ ПРИРОДНЫХ И ТЕХНОЛОГИЧЕСКИХ ГАЗОВЫХ СМЕСЕЙ ПЕРТРАКЦИЕЙ НА НАНОПОРИСТЫХ МЕМБРАНАХ

Изобретение относится к области мембранного газоразделения и может быть использовано для удаления нежелательных компонентов природных и технологических газовых смесей. Cпособ удаления компонентов газовых смесей, основанный на прохождении компонентов газовой смеси через нанопористую мембрану с последующим их селективным поглощением жидким абсорбентом, находящимся в контакте с нанопористой мембраной, в котором для предотвращения попадания газа в жидкую фазу абсорбента и жидкой фазы абсорбента в газовую фазу используют нанопористую мембрану с однородной пористостью (дисперсия по размерам менее 50%) и диаметром пор в диапазоне 5-500 нм, а разность давлений между газовой фазой и жидким абсорбентом поддерживают ниже давления точки пузырька мембраны, производительность отбора кислых газов (более 0,3 нм/(мчас) по СО) при плотности упаковки половолоконной мембраны до 3200 м/м, что соответствует удельной объемной производительности удаления кислых газов до 1000 нм/(мчас). Технический результат – ...

СПОСОБ ИНГИБИРОВАНИЯ ОБРАЗОВАНИЯ КЛАТРАТ-ГИДРАТОВ В ЖИДКОСТИ

Описывается способ ингибирования образования клатрат-гидратов в жидкости, содержащей гидратобразующие составляющие путем обработки жидкости ингибитором, содержащим в значительной степени растворимый в воде полимер, отличающийся тем, что в качестве полимера используют полимеру с мол.м. 1000-6000000, с основной полимерной цепью, которая имеет по меньшей мере две боковые группы, первая из них содержит не менее двух атомов, выбранных из группы: углерод, азот и кислород, а вторая представляет собой С1-С3 алкил. Технический результат - упрощение процесса. Ингибиторы по данному изобретению эффективно воздействуют на жидкий нефтепродукт, содержащий водную фазу. 16 з.п.ф-лы, 1 табл.

СПОСОБ ПОДГОТОВКИ УГЛЕВОДОРОДНОГО ГАЗА

Изобретение относится к способам подготовки углеводородных газов путем низкотемпературной сепарации и может быть использовано для подготовки попутного нефтяного газа в нефтяной промышленности. Углеводородный газ 1 компримируют на первой ступени 2 с охлаждением компрессата внешним хладагентом в условиях дефлегмации,с получением конденсата 4 и сжатого газа 5, который компримируют на второй ступени 6 с охлаждением компрессата внешним хладагентом (не показан) и газом низкотемпературной сепарации, который затем выводят в качестве подготовленного газа 7, с получением конденсата 8 и сжатого газа 9, который редуцируют с помощью устройства 10 и разделяют на подготовленный газ 7 и конденсат 12, который редуцируют с помощью устройства 13 и деэтанизируют в сепараторе 16 совместно с редуцированными в устройствах 14 и 15 конденсатами 4 и 8 первой и второй ступеней 2 и 6 с получением товарного конденсата 17 и газа деэтанизации 3, который рециркулируют на первую ступень 2 компримирования. При необходимости ...

УСТРОЙСТВО ПОДГОТОВКИ ПОПУТНЫХ НЕФТЯНЫХ ГАЗОВ ДЛЯ ИСПОЛЬЗОВАНИЯ В ЭНЕРГОУСТАНОВКАХ

Полезная модель относится к нефтяной и газовой промышленности, в частности к системам утилизации и использования попутных нефтяных и сырых природных газов в энергетике. Устройство подготовки каталитической конверсией попутных нефтяных или сырых природных газов для использования в энергоустановках состоит из системы запуска, системы подачи и дозирования реагентов, конвертора, теплообменников, системы управления, в конверторе установлено два слоя катализаторов, позволяющих конвертировать в метан соединения, присутствующие в попутных нефтяных и сырых природных газах, имеющие низкую детонационную стойкость и повышающие вероятность смоло- и сажеобразования. Технический результат - возможность эффективной утилизации и полезного использования попутных нефтяных или сырых природных газов в энергоустановках. 1 н.п., 7 з.п. ф-лы, 1 илл.

УСТРОЙСТВО КОМБИНИРОВАННОЙ ОЧИСТКИ ГАЗА

Устройство комбинированной очистки газа, которое содержит абсорбционный блок гликолевого типа, подключенный через блок дозированной подачи газа на очистку к газохранилищу, и адсорбционный блок глубокой очистки, связанный с трубопроводом потребителя очищенного газа, отличающееся тем, что блок глубокой адсобционной очистки включает целлюлозноацетатные, полисульфонные, полиаримидные или керамические углеродоволокнистые мембраны, причем устройство снабжено блоком измерения пропускной способности, который подключен выходом через блок сравнения с заданной нормированной пропускной способностью и механизм конвейерного перемещения мембран к регенерационному блоку восстановления, выход которого соединен через бункер накопления регенерированных мембран, второй вход которого запитан от склада новых мембран, с блоком глубокой мембранной очистки, причем регенерационный блок вторым своим входом соединен с блоком выработки агента термо-, вибро-, гидро- или газодинамической регенерации мембран, а второй ...

УСТАНОВКА ПАРОВОЙ КОНВЕРСИИ СЕРНИСТОГО УГЛЕВОДОРОДНОГО ГАЗА

Изобретение раскрывает установку паровой конверсии сернистого углеводородного газа, которая оснащена линией ввода сырьевого газа и линией вывода конвертированного газа с рекуперационным устройством, включает также нагреватель и конвертор, при этом установка оборудована узлом адсорбционного обессеривания, состоящим, по меньшей мере, из двух переключаемых адсорберов, по меньшей мере один из которых, находящийся в режиме регенерации адсорбента, соединен с линией вывода конвертированного газа в дефлегматор, установленный в качестве рекуперационного устройства и оснащенный линией вывода подготовленного газа, а остальные адсорберы, находящиеся в режиме адсорбции, установлены на линии ввода сырьевого газа, кроме того, установка оснащена блоком подготовки воды, соединенным линией подачи подготовленной воды с линией подачи сырьевого газа после адсорбера и оснащенным линиями ввода воды, подачи дегазированного водного конденсата из дефлегматора и вывода солевого концентрата, при этом нагреватель установлен ...

Способ удаления диоксида углерода и сероводорода из метансодержащих газовых смесей

Изобретение относится к способам селективного удаления диоксида углерода и сероводорода из метансодержащих газовых смесей гибридным методом мембранно-абсорбционного газоразделения и может быть использовано в газовой, нефтяной и других отраслях химической промышленности. Способ селективного удаления диоксида углерода и сероводорода из метансодержащих газовых смесей, состоящий из мембранно-абсорбционного модуля для газоразделения высокого давления, где процесс удаления диоксида углерода и сероводорода проводится в объеме одного массообменного аппарата, подача питающей газовой смеси осуществляется в мембранно-абсорбционный модуль при абсолютном давлении 5 бар в жидкий абсорбент, находящийся на поверхности непористой мембраны с селективным слоем, при этом удаление диоксида углерода и сероводорода из метансодержащих газовых смесей и регенерация абсорбента происходит без дополнительных энергозатрат в результате создания движущей силы за счет градиента давления и последующей десорбции растворенного ...

Ингибитор гидратообразования и коррозии на основе полиуретана, содержащего фрагменты дибутиламина

Настоящее изобретение относится к ингибиторам гидратообразования и коррозии на основе полиуретанов формулы I, включая изомеры: , где сумма n, m, x и p представляет собой число, достаточное для получения средней молекулярной массы 4 кДа. Данные ингибиторы могут найти применение в нефтегазовой отрасли в процессах добычи, подготовки и транспортировки углеводородного сырья для предотвращения образования газовых гидратов и коррозии. 2 ил., 3 пр.

СПОСОБ ИНГИБИРОВАНИЯ ОБРАЗОВАНИЯ ГИДРАТОВ

Описывается способ ингибирования образования гидратов клатрата в текучей среде, содержащей гидратообразующие компоненты, включающий обработку текучей среды в качестве ингибитора водорастворимым полимером или сополимером, содержащим N-виниламидное звено формулы I где R1 является водородом или углеводородной группой, имеющей от одного до шести атомов углерода, R2 является углеводородной группой, имеющей от одного до шести атомов углерода, при этом общая сумма углеродных атомов R1 и R2 больше или равна 1, но меньше 8, и х представляет среднее число звеньев, необходимых для получения молекулярной массы полимера между около 1000 и около 6000000. Способ может быть использован при обработке потока нефтяной текучей среды, например природного газа, транспортируемого в трубопроводе, для ингибирования образования гидратных пробок в трубопроводе. Технический результат - предотвращение образования гидратных пробок. 2 с. и 21 з.п. ф-лы, 1 табл.

СПОСОБ ПОЛУЧЕНИЯ СИНТЕЗ-ГАЗА ДЛЯ ПРОИЗВОДСТВА МЕТАНОЛА

Изобретение относится к области переработки природного газа, а именно к способу получения синтез-газа для производства метанола, а также может быть использовано на предприятиях химической и нефтехимической промышленности, производящих метанол. Способ заключается в двухступенчатой парокислородной конверсии природного газа, которая включает очистку углеводородного сырья от сернистых соединений, испарение газового конденсата в сатураторе с насыщением природного газа водяным паром, дополнительное смешение природного газа с водяным паром с образованием парогазовой смеси, первую ступень конверсии в трубчатом реакторе, вторую ступень конверсии в шахтном конверторе и ступенчатую утилизацию тепла конвертированного газа, причем часть низкопотенциального тепла конвертированного газа, поступающего на синтез метанола, отводят с помощью теплового насоса для испарения газового конденсата при температуре 215-220°С для получения технологического пара с давлением 2,1-2,3 МПа. Технический результат заключается ...

БЛОК ОЧИСТКИ ГАЗА ОТ СЕРОВОДОРОДА

... 1. Блок очистки газа от сероводорода путем его сжижения при низких температурах, имеющий холодный блок с дистилляционной колонной для выделения сжиженного сероводорода, отличающийся тем, что холодный блок приведен в тепловой контакт с термоакустическим холодильником, который волноводом соединен с термоакустическим двигателем, горелка которого соединена с выходной магистралью очищенного газа.2. Блок по п.1, отличающийся тем, что с выходной магистралью очищенного газа противоточным теплообменником связана входная магистраль очищаемого газа.

СПОСОБ ДОБАВЛЕНИЯ ПЛОХО ПАХНУЩЕГО ОДОРАНТА К ПОТРЕБИТЕЛЬСКОМУ ГАЗУ И ГАЗОВАЯ СМЕСЬ ДЛЯ ДОБАВЛЕНИЯ К ПОТРЕБИТЕЛЬСКОМУ ГАЗУ

Использование: в производстве потребительского газа, в частности в способе добавления плохопахнущего одоранта к потребительскому газу и к газовой смеси. Сущность изобретения: способ предусматривает растворение плохопахнущего одоранта в растворителе в сосуде, работающем под давлением, с получением жидкой фазы, состоящей из раствора плохопахнущего одоранта в сконденсированном газе и газовой фазы. Затем жидкую фазу испаряют из сосуда. Полученную паровую фазу смешивают с потребительским газом. В качестве плохопахнущего одоранта используют сероорганические соединения или смесь из двух или более сероорганических соединений, выбранных из группы, включающей тетрагидротиофен, C1-C4 -алкилмеркаптан, диметил или диэтилсульфид, метилэтилсульфид. В качестве растворителя используют конденсированную двуокись углерода, шестифтористую серу или закись азота. 2 с. и 8 з.п.ф-лы.

ТВЕРДЫЙ СОСТАВ ДЛЯ ХРАНЕНИЯ И ТРАНСПОРТИРОВКИ ПРИРОДНЫХ ГАЗОВ

Использование: применение и транспортировка природных газов без сосудов высокого давления. Сущность изобретения: клатратное соединение включения природных газов с фторированным графитом общего состава Cx FCly•zCnH2n+2, где x= 1,8-2,5; y=0, 08-0,09; z=0,12-0,22, CnH2n+2 - метан, этан, пропан, бутан. Продукт не содержит примесей графита, устойчив до 80oC, не изменяет состав при обработке водой при 20-30oC, плотность 2,2 г/см3, давление диссоциации при 22oC не превышает 10-4 атм.

Промотор гидратообразования на основе сульфосукцинатов спиртов

Изобретение относится к химической промышленности, конкретно к промоторам гидратообразования на основе сульфосукцинатов спиртов формулы R-O-C(=O)-CH2-CH(-SO3Na)-COOH, применяемым в нефтегазовой отрасли в процессах добычи, транспортировки и хранения природного газа. Техническим результатом изобретения является предоставление сульфосукцинатов спиртов, способных эффективно промотировать гидратообразование. 2 н.п. ф-лы, 2 ил., 22 пр.

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Изобретение относится к вспомогательному оборудованию ректификационных колонн и может быть использовано в нефтегазовой промышленности. Предложено два варианта системы подготовки углеводородного газа, которая в обоих вариантах включает сепараторы 1-3, дефлегматор 4 и редуцирующие устройства 5-7. Во втором варианте система дополнительно включает четвертый сепаратор 8 и редуцирующее устройство 9. При работе первого варианта системы углеводородный газ подают в сепаратор 1, где разделяют на газ и остаток, который редуцируют в устройстве 5 и разделяют в сепараторе 2 на газ, выводимый из системы, и остаток, который подают в верхнюю часть деметанизатора 10 по первой снизу линии. Газ из сепаратора 1 направляют в дефлегматор 4, в котором в условиях дефлегмации разделяют на газ и остаток, который редуцируют в устройстве 6 и подают в верхнюю часть деметанизатора 10 по второй снизу линии. Газ из дефлегматора 4 направляют в сепаратор 3, где разделяют на газ, выводимый из системы, и остаток, который подают ...

Газоперерабатывающий завод

Настоящее изобретение относится к криогенной технике и может быть использовано в газовой промышленности для переработки углеводородных газов. Предложен газоперерабатывающий завод, включающий установку выделения фракции углеводородов С2+, которая включает расположенные на линии очищенного и осушенного газа компрессорную секцию первого детандер-компрессорного агрегата, основной многопоточный теплообменник, сепаратор, оснащенный линиями вывода газа сепарации и остатка сепарации. Причем линия вывода газа сепарации разделена на линии подачи первого и второго газов сепарации, линия вывода остатка сепарации разделена на линии подачи первого и второго остатков сепарации, при этом линия подачи первого остатка сепарации соединена с линией подачи первого газа сепарации, оснащенной верхним многопоточным теплообменником, редуцирующим вентилем и соединенной с верхней частью ректификационной колонны, линия подачи второго остатка сепарации оснащена редуцирующим вентилем и соединена со средней частью ректификационной ...

СПОСОБЫ И УСТАНОВКИ ДЛЯ ПОЛУЧЕНИЯ СЖИЖЕННОГО ПРИРОДНОГО ГАЗА

Предложены способ и установка получения сжиженного природного газа из подаваемого природного газа, содержащего углеводороды C5-C7 и углеводороды C8 или выше. Причем указанный способ включает стадии: контактирования первого адсорбента, который предпочтительно адсорбирует углеводороды C8 или выше, с подаваемым природным газом, для получения обедненного C8 потока природного газа; контактирования второго адсорбента, отличающегося от первого адсорбента и предпочтительно адсорбирующего углеводороды C5-C7, с обедненным C8 потоком природного газа, для получения обедненного C5-C8 потока природного газа, при этом второй адсорбент имеет более высокую селективность и емкость адсорбции углеводородов C5-C7, чем первый адсорбент; и сжижения обедненного C5-C8 потока природного газа в ступени сжижения. Использование настоящего изобретения позволяет избежать чрезмерной регенерации адсорбентов. 2 н. и 8 з.п. ф-лы, 2 табл., 5 ил.

СПОСОБ РАЗДЕЛЕНИЯ ГАЗОВОГО ПОТОКА И УСТРОЙСТВО ДЛЯ ЕГО ОСУЩЕСТВЛЕНИЯ (ВАРИАНТЫ)

Поток углеводородного газа, содержащего компоненты С1, С2 и С3, разделяют на летучую фракцию, включающую основную часть С1 и C2, и на более тяжелые углеводородные компоненты, содержащие основную часть пропана и пропилена. Поток охлаждается и/или расширяется до частичной конденсации, затем разделяется с получением первого потока пара, который направляется в контактирующее устройство (абсорбер), где отделяют третий поток пара и поток жидкости, содержащей C3. Поток жидкости, содержащей C3, направляется в дистилляционную колонну, где отделяется второй поток пара, содержащий основную часть компонентов C3 и более тяжелых углеводородных компонентов. Затем второй поток пара подвергается тепловому обмену с третьим потоком пара для охлаждения второго потока пара и конденсации, по крайней мере, его части с образованием конденсированного потока. По крайней мере, часть конденсированного потока направляется в контактирующее устройство (абсорбер) для тесного контакта с первым потоком пара. Оставшаяся ...

СПОСОБ ДОСТАВКИ ПРИРОДНОГО ГАЗА ПОТРЕБИТЕЛЮ

Изобретение относится к способу доставки природного газа потребителю. Способ включает получение газовых гидратов, их перемещение потребителю, разложение газогидрата с получением газа и характеризуется тем, что газогидрат получают в виде водогидратной пульпы с содержанием частиц газогидрата около 50% ее объема. При этом процесс получения газовых гидратов осуществляют при термодинамических параметрах, соответствующих образованию газогидрата, с отбором тепла от смеси природного газа и воды водоледяной пульпой, предпочтительно, с крупностью частиц не более 10 мкм, с содержанием частиц льда около 50% объема водоледяной пульпы, которые равномерно распределяют по объему реактора, перевозку газогидратной пульпы осуществляют в герметичных, теплоизолированных грузовых помещениях транспортного средства, при термодинамических параметрах, исключающих разложение газогидрата, причем разложение газогидратной пульпы с отбором газа, по завершению его перевозки, осуществляют снижением давления в грузовом ...

СПОСОБ УДАЛЕНИЯ ЭЛЕМЕНТАРНОЙ СЕРЫ, ПРИСУТСТВУЮЩЕЙ В ГАЗЕ

Изобретение относится к способу удаления элементарной серы, присутствующей в газе в форме пара и/или увлеченных частиц, в котором обрабатываемый газ охлаждают до температуры между точкой конденсации паров воды и 120oC. Обрабатываемый газ с температурой 120-300oC вводят в теплообменник в его нижнюю часть и с помощью температуры и/или скорости течения охлаждающей среды обеспечивают температуру стенки теплообменника ниже точки отверждения серы и выше точки конденсации воды, если какое-либо количество таковой присутствует в газе. Осажденная сера удаляется под действием гравитации в противоточном с обрабатываемым газом потоке. Процесс осуществляют в трубчатом или пластинчатом теплообменнике, расположенном вертикально или наклонно, 10 з.п. ф-лы, 2 ил.

СПОСОБ УДАЛЕНИЯ КИСЛОТНОГО ГАЗА ИЗ НЕОБРАБОТАННОГО ГАЗА И ДОБАВКА, ОБЛАДАЮЩАЯ ПОДАВЛЯЮЩИМ КОРРОЗИЮ ЭФФЕКТОМ И ПРОТИВОПЕННЫМ ЭФФЕКТОМ, ДЛЯ ДОБАВЛЕНИЯ К РАСТВОРУ АМИНА ДЛЯ УДАЛЕНИЯ КИСЛОТНОГО ГАЗА

... 1. Способ удаления кислотного газового компонента из необработанного газа, включающий взаимодействие необработанного газа, содержащего кислотный газовый компонент, с водным раствором алканоламина, в котором присутствует композиция, содержащая органополисилоксан, имеющий полиоксиалкиленовую группу, и мелкозернистый порошок кремнезема. 2. Способ удаления кислотного газового компонента из необработанного газа по п.1, в котором композиция, содержащая органополисилоксан, имеющий полиоксиалкиленовую группу, и мелкозернистый порошок кремнезема возможно добавлена, основываясь на состоянии пенообразования в системе удаления кислотного газа, снаружи системы. 3. Способ удаления кислотного газа из необработанного газа по п.1, в котором используют водный раствор алканоламина, в котором содержится композиция, содержащая органополисилоксан, имеющий полиоксиалкиленовую группу, и мелкозернистый порошок кремнезема. 4. Способ удаления кислотного газового компонента из необработанного газа по п.1, в котором ...

СИСТЕМА ОБРАБОТКИ ГОРЮЧЕГО ГАЗА И СПОСОБ ОБРАБОТКИ ГОРЮЧЕГО ГАЗА

... 1. Система обработки горючего газа для получения сжимаемого горючего газа, содержащего заданный горючий газ в качестве его основного компонента, подлежащего сжатию компрессором в сжатый горючий газ, отличающаяся тем, что: ! данная система содержит средство каталитического сжигания для приема кислородсодержащего горючего газа, который содержит кислород в добавление к горючему газу являющимся его основным компонентом, обеспечивающее контактирование этого кислородсодержащего горючего газа с катализатором окисления для его частичного сгорания с получением, в результате, частично сожженного газа в качестве упомянутого сжимаемого горючего газа. ! 2. Система обработки горючего газа по п.1, отличающаяся тем, что упомянутый горючий газ представляет собой метан или водород. ! 3. Система обработки горючего газа по п.1 или 2, отличающаяся тем, что данная система дополнительно содержит средство удаления воды для приема сжимаемого горючего газа до его подачи в компрессор и удаления воды из этого сжимаемого ...

Мембранный контактор для очистки природных и технологических газов от кислых компонентов

Изобретение относится к области мембранного газоразделения и может быть использовано для удаления нежелательных компонентов природных и технологических газовых смесей. Устройство мембранного контактора для очистки природных и технологических газов от кислых компонентов посредством абсорбции через нанопористую мембрану, включающее мембранный модуль, подключенный входами и выходами к линиям подачи и сброса газовой и жидкой фаз, содержащий один или несколько размещенных в горизонтальной плоскости и соединенных параллельно контакторных элементов, с газоплотно установленной в каждом элементе нанопористой мембраной, имеющей средний диаметр пор в диапазоне 5-500 нм и распределение пор по размерам, не превышающее 100%, установленной в модуле с обеспечением возможности подачи очищаемой газовой фазы внутрь контакторного элемента, обеспечением контакта мембраны с газовой фазой с одной стороны мембраны и с жидкой фазой абсорбента с противоположной стороны и возможностью обтекания мембраны потоком абсорбента ...

РАСТВОРИТЕЛЬ НА ОСНОВЕ ТЯЖЕЛЫХ УГЛЕВОДОРОДОВ

Предложен растворитель на основе тяжелых углеводородов, являющихся отходами производства сжиженного природного газа, полученный в процессе переработки природного газа в сжиженный природный газ, состоящий из компонентов исходного природного газа, при этом растворитель имеет следующем состав, мас. %: пропан - от 0 до 0,5; бутаны - от 2 до 5; пентаны - от 8 до 12; гексаны - от 14 до 18; гептаны - от 12 до 14; октаны - от 4 до 7; нонаны - от 0 до 4; деканы - от 0 до 2; алкил-циклопентаны - от 10 до 15; алкил-циклогексаны - от 23 до 28; ароматические углеводороды - от 2 до 4; бициклические углеводороды - от 2 до 4; эфиры - от 0,5 до 2; адамантаны - от 0,5 до 2. Технический результат – органический растворитель, удаляющий до 100% масляной пленки с металлической, стеклянной, керамической или пластмассовой поверхности, подходящий для применения в любых климатических районах и в любое время года. 1 пр.

ОБЪЕДИНЕННЫЙ СПОСОБ УДАЛЕНИЯ ТЯЖЕЛЫХ УГЛЕВОДОРОДОВ, АМИНОВОЙ ОЧИСТКИ И ОСУШКИ

... 1. Способ очистки сырьевого потока сырого природного газа, который включает следующие стадии: ! (1) пропускание указанного сырьевого потока сырого природного газа через секцию абсорбции, содержащую адсорбент, селективный для удаления тяжелых углеводородов и воды из указанного сырьевого потока природного газа, и таким образом образование первого выходящего потока; ! (2) введение указанного первого выходящего потока в контакт с водным аминовым абсорбентом, где указанный водный аминовый абсорбент удаляет кислые газы из указанного первого выходящего потока, таким образом, образование продуктового потока природного газа, имеющего меньшее, чем в указанном первом выходящем потоке, содержание кислых газов; ! (3) рециркулирование указанного продуктового потока природного газа через указанную секцию абсорбции, содержащую адсорбент, селективный для удаления воды; и ! (4) сбор продуктового потока природного газа, содержащего меньшее, чем в указанном потоке сырого природного газа, количество воды и ...

УСТАНОВКА ДЛЯ ВЫДЕЛЕНИЯ МЕТАНА ИЗ ВЕНТИЛЯЦИОННЫХ ВЫБРОСОВ УГОЛЬНЫХ ШАХТ

СПОСОБ ОЧИСТКИ И ОСУШКИ ПРИРОДНОГО И ПОПУТНОГО НЕФТЯНОГО ГАЗОВ С ВЫСОКИМ СОДЕРЖАНИЕМ СЕРОВОДОРОДА И УСТРОЙСТВО ДЛЯ ЕГО ОСУЩЕСТВЛЕНИЯ

Способ очистки и осушки природного и попутного нефтяного газов от сероводорода, отличающийся тем, что технологический процесс очистки и осушки газов, включающий получение диоксида серы сжиганием серы и серосодержащих соединений в печи, его смешение с растворителем, промывку этим раствором исходного газа от сероводорода с получением элементарной серы и воды, выведение суспензии серы и отделение серы от растворителя, возвращение растворителя и части серы в технологический процесс очистки, а также осушку газа за счет поглощения воды из газа проводят в два этапа, при которых вначале исходный газ промывают водным раствором сернистой, серной кислот и диоксида серы, полученных путем очистки дымовых газов, образовавшихся при сжигании регенерационных газов и частично серы в топке котла, а затем производят окончательную очистку и осушку газа на твердых адсорбентах и при этом утилизируют тепло от сжигания регенерационных газов и серы.

УСТРОЙСТВО ПОДГОТОВКИ ПОПУТНЫХ НЕФТЯНЫХ ГАЗОВ ДЛЯ ИСПОЛЬЗОВАНИЯ В ЭНЕРГОУСТАНОВКАХ И СПОСОБ ЕГО РАБОТЫ

... 1. Устройство подготовки попутных нефтяных или сырых природных газов посредством каталитической конверсии для использования в энергоустановках, состоящее из системы запуска, системы подачи и дозирования реагентов, конвертора, теплообменников, системы управления, отличающееся тем, что в конверторе установлен, по крайне мере, один слой катализатора, позволяющего при температуре не выше 450°С конвертировать в метан соединения, присутствующие в попутных нефтяных или сырых природных газах, имеющие низкую детонационную стойкость и повышающие вероятность смоло- и сажеобразования. ! 2. Устройство по п.1, отличающееся тем, что в конверторе расположен катализатор, в качестве активного компонента которого используют различные комбинации оксидов алюминия, кремния, переходных и редкоземельных элементов 4-6 периодов, в основном, четвертого и пятого периодов, преимущественно, Сu, Со, Ni, Fe, Cr, Mn, Ti, Zr, La, Ce, Y, Sm, Pr, Gd, и металлов платиновой группы, в основном, Pt, Pd, Rh, Ir, Ru, преимущественно ...

КОМПОЗИЦИЯ И СПОСОБ СНИЖЕНИЯ АГЛОМЕРАЦИИ ГИДРАТОВ

... 1. Композиция, включающая соединение следующей формулы и необязательно его соли:где R, Rи Rкаждый независимо представляет собой CHили бензил;где Rпредставляет собой С-Салкил или алкенил;n обозначает целое число от 0 до 10; иXпредставляет собой противоион;необязательно дополнительно включающая по меньшей мере один полярный или неполярный растворитель или их смесь.2. Композиция по п.1, в которой каждый алкил независимо выбран из группы, состоящей из линейного алкила, разветвленного алкила, циклического алкила, насыщенного варианта вышеизложенных, ненасыщенного варианта вышеизложенных и их комбинации.3. Композиция по п.1, в которой алкил для каждого из R, Rи Rнезависимо выбран из группы, состоящей из метила, этила, пропила, бутила, пентила, гексила, гептила, октила, нонила, децила и их комбинаций.4. Композиция по п.1, в которой алкил в Rвыбран из группы, состоящей из бутила, пентила, гексила, гептила, октила, нонила, децила и их комбинаций.5. Композиция по п.1, в которой Rи Rпредставляют собой ...

Способ переработки топлива, получаемого из отходов, и устройство дл его осуществлени

... 1. Способ переработки топлива, получаемого из отходов, с получением из него топливного газа при помощи термического крекинга, отличающийся тем, что материал подвергают деаэрации, получают слой материала в вакууме при изоляции от внешнего воздействия (в камере термического крекинга) при температуре от 400 до 600°С, поддерживаемой при помощи противоточно направленного потока горячих газов, которые охватывают материал; подают материал, прошедший камеру термического крекинга, в реактор, в котором его подвергают воздействию температур от 1200°С до 1800°С, вблизи входа камеры термического крекинга отводят газы, полученные в результате термического крекинга, а также отводят газы, покрывающие слой материала, для поддержания вакуума в камере термического крекинга, подают отведенные газы в разрядный трубопровод, предназначенный для газов, образующихся в реакторе, очищают и фильтруют полученные газы для их использования в качестве топливных газов. 2. Способ по п.1, отличающийся тем, что горячие газы ...

УСТАНОВКА КОМПЛЕКСНОЙ ПОДГОТОВКИ УГЛЕВОДОРОДНОГО КОНДЕНСАТА

СПОСОБ И УСТРОЙСТВО ДЛЯ ПРИСАДКИ ОДОРАНТА К ПОТРЕБИТЕЛЬСКОМУ ГАЗУ

Предлагаемые способ и устройство предназначены для присадки одоранта к потребительскому газу, который распределяют к пункту потребления, для того, чтобы дать знать людям, находящимся в зоне опасности возникновения пожара, взрыва, отравления, удушения или иных опасностей, в случае, если потребительский газ истекает в окружающую атмосферу. Одорант растворяют в конденсированном разбавительном газе в емкости 3 под давлением, получая раствор эталонного газа, который включает жидкую фазу 6 и газообразную фазу 7. Потребительский газ разбавляют подходящим количеством жидкой фазы эталонного газа, которую испаряют прежде, чем смешать с потребительским газом. С этой целью устройство содержит средства для корректирования соотношения между двумя газовыми потоками во время процесса разбавления в зависимости от повышения концентрации одоранта в жидкой фазе 6 эталонного газа, что приводит в результате к снижению соотношения между количеством жидкого газа и газообразной фазы 7 в емкости под давлением. Это ...

ОДОРАНТ ДЛЯ СЖИЖЕННОГО УГЛЕВОДОРОДНОГО ГАЗА

Изобретение относится к одорантам, применяемым для одоризации сжиженных углеводородных газов, и может быть использовано в газонефтеперерабатывающей и химической промышленности. Цель изобретения - повышение устойчивости запаха и снижение стоимости одоранта, а также уменьшение его растворимости в воде. Поставленная цель достигается одорантом для сжиженного углеводородного газа на основе алкилмеркаптанов C2 - C4, который в качестве алкилмеркаптанов C2 - C4 содержит кубовый остаток ректификационной колонны выделения индивидуального этилмеркаптана из смеси природных меркаптанов и дополнительно содержит 20 - 65 мас.% продукта окислительно-каталитического обезвреживания метилмеркаптансодержащих технологических выбросов. При этом в качестве алкилмеркаптанов C2-C4 он содержит кубовый остаток ректификационной колонны, включающий этил-, пропил- и бутилмеркаптаны при следующем соотношении компонентов, мас.%: этилмеркаптан 3 - 5, пропилмеркаптан 85 - 94, бутилмеркаптан остальное. Кроме того, он дополнительно ...

УСТРОЙСТВО ДЛЯ ЭНДОТЕРМИЧЕСКОЙ РЕАКЦИИ

Эндотермическая реакционная печь 102 содержит одну или более удлиненных труб 110, разделяющих ее внутреннюю часть на проточный канал для реакционной среды и проточный канал для горючей среды для проведения эндотермической реакции. Проточный канал для горючей среды расположен так, что топливо и горючий воздух нагреваются отдельно внутри печи 102 до температуры, значительно превышающей их температуру самовоспламенения, до соединения в зоне 116 сгорания, где они смешиваются, самовоспламеняются и сгорают.

КОМПОЗИЦИИ ДЛЯ УДАЛЕНИЯ СЕРОВОДОРОДА И МЕРКАПТАНОВ

Способ удаления ртути из потока природного газа

Изобретение относится к технологии очистки природного газа от ртути перед использованием его в каталитических процессах и для предотвращения коррозии оборудования. Цель изобретения - исключение замены отработанного сорбента. Поток очищаемого природного газа и сорбента подают в зону контакта в абсорбер. Контактирование сорбента с природным газом ведут при повышенном давлении. В качестве сорбента используют свободные от ртути смесь этана, пропана и бутана, или пропана и бутана, сжиженную при охлаждении, или бензин. После контактирования обеднен ный ртутью природный газ выводят из зоны контакта. Обогащенный ртутью сорбент также выводят из зоны контакта, выделяют из него ртуть охлаждением в жидком или твердом виде и рециркулируют в зону контакта с природным газом. При использовании ожиженной смеси этана, пропана и бутана или пропана и бутана ее температуру в зоне контакта с газом поддерживают от +10 до -85amp;deg;С, а давление газа - 17-105 кг/см2. При использовании бензина его температуру ...

Zeolitisches Molekularsieb, Verfahren zu dessen Herstellung und dessen Verwendung

A zeolitic molecular sieve is described, the cavities of which are partially blocked. This partial blocking essentially concerns the beta cages which are preferably 50 to 100 % blocked. Preferred blocking agents are alkali metal and/or alkaline-earth metal salts with mono- or bivalent anions. The incorporation of these salts for partially blocking the cavities of the molecular sieve takes place during or after the synthesis of the zeolite. The zeolitic molecular sieve according to the invention is suitable for separating components from gases, in particular for purifying gases such as for example for desulphurizing natural gas.

Verfahren und Vorrichtung zur Reinigung von Gasen

Verfahren zum Betreiben einer stationären Kraftanlage sowie mit dem Verfahren betriebene stationäre Kraftanlage

Verfahren zum Betreiben einer stationären Kraftanlage (1) umfassend einen Gasmotor (2) mit mindestens einer Vorkammer (3) und mindestens einem Hauptbrennraum (4), wobei der stationären Kraftanlage (1) ein – insbesondere im Wesentlichen kontinuierlicher – Gasstrom (5) zugeführt wird, der ein schwer entflammbares Gas umfasst, und wobei in der stationären Kraftanlage (1) der Gasstrom (5) in einen Hauptstrom (5a) und in einen Teilstrom (5b) aufgeteilt wird, wobei der Hauptstrom (5a) dem mindestens einen Hauptbrennraum (4) zugeführt wird und wobei der Teilstrom (5b) zur Erhöhung der Entflammbarkeit aufbereitet und der mindestens einen Vorkammer (3) des Gasmotors (2) zugeführt wird, dadurch gekennzeichnet, dass der stationären Kraftanlage (1) ein Gasstrom (5) zugeführt wird, der eine erste laminare Flammengeschwindigkeit (V1) aufweist, die kleiner gleich 15 cm/s, vorzugsweise kleiner gleich 12 cm/s, besonders bevorzugt kleiner gleich 10 cm/s, bei einem Verbrennungsluftverhältnis von 1 ist, wobei ...

GAS TREATMENT PROCESS

PROCESS FOR THE PURIFICATION OF A GASEOUS MIXTURE CONTAINING UNDESIRABLE GASEOUS COMPOUNDS

VERFAHREN UND VORRICHTUNG ZUM MISCHEN DES EINEM SCHNEIDBRENNER ZUGEFUEHRTEN BRENNGASES MIT EINEM FLUESSIGEN ZUSATZSTOFF

Filtervorrichtung, Biomassevergasungsanlage sowie Verwendung einer Panzertresse als Filtermedium

Filtervorrichtung (8) zum Filtern von durch Vergasung von Biomasse erzeugtem Brenngas, mit einem Filterkörper (11), welcher ein Filtermedium (23) aufweist, das als Gewebe (23) ausgebildet ist, wobei das Gewebe (23) als Panzertresse ausgebildet ist.

Verfahren und Anlage zum Beheizen von Regeneratoren bei der Trocknung von Erdgas

METHODE UND VORRICHTUNG ZUM TRANSPORT VON GEKÜHLTEM ERDGAS

FISCHER-TROPSCH VERFAHREN

Verfahren zum Abtrennen von Stickstoff aus Erdgas

Es wird ein Verfahren zum Verflüssigen einer kohlenwasserstoffreichen, stickstoffenthaltenden Einsatzfraktion, vorzugsweise Erdgas, beschrieben. Erfindungsgemäß wird a) die Einsatzfraktion (1) verflüssigt (E1, E2), b) rektifikatorisch (T1) in eine stickstoffangereicherte Fraktion (9), deren Methangehalt max. 1 Vol.-% beträgt, und eine kohlenwasserstoffreiche, stickstoffabgereicherte Fraktion (4) aufgetrennt, c) die kohlenwasserstoffreiche, stickstoffabgereicherte Fraktion (4) unterkühlt (E3) und entspannt (b), d) die entspannte kohlenwasserstoffreiche, stickstoffabgereicherte Fraktion (5) in eine kohlenwasserstoffreiche Fraktion (6), deren Stickstoffgehalt max. 1 Vol.-% beträgt, und eine stickstoffreiche Fraktion (7) aufgetrennt (D1), und e) die stickstoffreiche Fraktion (7) der Einsatzfraktion (1) zugemischt.

Verwendung von hydrophobiertem Kieselgel als selektives Sorbens zur Entfernung von organischen Siliziumverbindungen

Verwendung von hydrophobiertem Kieselgel als Sorbens für die selektive Entfernung siliziumorganischer Verbindungen aus biogenen und/oder anthropogenen Gasen.

Brennstoffgas für eine Brennstoffzelle

Brennstoffgas für eine Brennstoffzelle, dadurch gekennzeichnet, dass es umfasst: ein Reaktionsgas, das zu einer Brennstoffzelle zugeführt wird und das durch eine chemische Reaktion Elektrizität erzeugt; und ein Geruchsstoff, der zu dem Reaktionsgas zugegeben wird, der einen Elektrodenkatalysator und einen Elektrolyten in der Brennstoffzelle nicht vergiftet und der sich in Wasser löst, so dass sein Geruch verschwindet.

VERFAHREN ZUR ABSORPTION VON ELEMENTAREM SCHWEFEL AUS ERDGAS DURCH ANWENDUNG VON MINERALOEL UND AEHNLICHEN FLUESSIGEN KOHLENWASSERSTOFFEN

Pipeline hydrate inhibitor and method of reducing hydrates using the hydrate inhibitor

A method for reducing hydrate formation in a hydrocarbon production pipeline system comprises: introducing an aqueous composition comprising an acetate salt into the hydrocarbon production pipeline system; and flowing a hydrocarbon there through, wherein the concentration of the acetate salt in the aqueous composition is adequate to reduce the formation of hydrates during hydrocarbon flow. Preferably, the acetate salt is potassium acetate or sodium acetate. Preferably, the aqueous composition introduced into the hydrocarbon production pipeline system has an acetate salt concentration ranging between 0.1% to 50% saturation in water at ambient conditions before introducing the aqueous composition into the pipeline system. The method may further comprise passing a pipeline pig through the hydrocarbon production pipeline system to remove bulk water there from. The method may also comprise pumping at least a first and a second slug of the aqueous composition into the pipeline system wherein ...

A filter device, and method of assembly

A filter device comprises two or more membrane filter units (108), each having an inlet opening for a fluid flow (F) to be processed,a first outlet opening for at least one portion (R) of said fluid flow and second outlet port for at least a remaining portion (P) of said fluid flow. The respective inlet openings of each membrane filter unit (108) are fluidly connected to a common inlet manifold (101; 203) and the respective first outlet openings of each membrane filter unit (108) are fluidly connected to a common outlet manifold (100; 200). At least one membrane filter unit (108) is arranged at a first position (L1) along a longitudinal axis (x1) and at least one membrane filter unit (108) is arranged at a second position (L2) along the longitudinal axis (x1), and the said two membrane filter units (108) are not axially aligned.

PLANT FOR PRODUCTION OF PROPANE-AIR GAS

A plant for the production of propane-air gas having a storage tank (2) for storing liquified propane gas, at least one air-heated type forced vaporizer for vaporizing (10) the liquified propane gas from the storage tank, at least one air mixer (22) for mixing the diluting the propane gas vaporized by the air-heated type forced vaporizer with air, and calorific-value-adjusting means comprising means for recovering part of the propane-air gas emerging from the air mixer, means for determining the calorific value thereof, and means for controlling on the basis of the determined value the quantity of air to be admitted to the air mixer. ...

A method for inhibiting hydrate formation

Removing carbon dioxide,ethane and heavier components from a natural gas

Hydroprocessing of hydrocarbons having a reduced sulfur content

A process for producing a hydrocarbon stream including C5-20 normal and iso-paraffins, comprises:

METHOD AND APPARATUS FOR PRODUCING A LIQUEFIED HYDROCARBON STREAM AND ONE OR MORE FRACTIONATED STREAMS FROM AN INITIAL FEED STREAM

Processing inert-rich natural gas streams

A process for processing of an inert-rich natural gas stream with a preferential physical solvent to obtain a specification-grade inert gas product, a specification-grade hydrocarbon gas product, and a specification-grade hydrocarbon liquids product. The process is an adaptation of the extractive flashing and extractive stripping versions of the Mehra Process.

Method of de-acidification in which acid gases are produced in liquid phase

Scrubbing CO2 from a gas stream containing methane and CO2 .

Separating CO 2 from a gas stream 10 containing methane and CO 2 comprises contacting the gas stream with an aqueous stream 11 so that at least a portion of the CO 2 is dissolved into the aqueous stream, separating the gas and aqueous streams 13 and disposing of the CO 2 in a marine environment, terrestrial formation or a combination thereof. The methane enriched gas stream may be converted into liquid hydrocarbons by the Fischer-Tropsch process. The aqueous stream may be at a pressure greater than atmospheric pressure but less than the source pressure of the gas stream. The aqueous stream, which prior to contact with the aqueous stream may have a pH of at least 7, may be obtained from one or more of reaction water or cooling water from a Fischer-Tropsch process, river water, non-potable water, sea water or water recovered from hydrocarbon production.

Gas hydrate inhibitor, method and use of hyperbranched polyester polyols as gas hydrate inhibitors

A method and system for lowering the water dew point of a hydrocarbon fluid stream subsea

The present invention concerns a method for lowering the water dew point subsea in a produced multiphase hydrocarbon fluid stream containing water, the method comprising the steps of: separating (10) the hydrocarbon fluid stream (1) into a liquid phase (3) and a first gas phase (2); cooling (20) the first gas phase in a controlled manner to knock out water or condensing water and optionally other condensates while keeping the fluid above a hydrate formation temperature thereof; separating off condensed liquids (6) and a second gas phase; wherein the second gas phase (8) has a water dew point which is lower than that of the initial multiphase hydrocarbon fluid stream. The invention also concerns a system for lowering the water dew point subsea.

Process for the elimination of mercaptans contained in gas

A process for the separation of mercaptans from gases, and especially from natural gas by absorption in a hydrocarbon oil and regeneration of the oil by oxidation of the mercaptans to sulfonic acids. The oxidation can be carried out at the absorption temperature and pressure by means of an oxidant in an aqueous medium. The regenerated oil is recycled after separation from the aqueous phase containing the sulfonic acids.

A method and system for lowering the water dew point of a hydrocarbon fluid stream subsea

The present invention concerns a method for lowering the water dew point subsea in a produced multiphase hydrocarbon fluid stream containing water, the method comprising the steps of: separating (10) the hydrocarbon fluid stream (1) into a liquid phase (3) and a first gas phase (2); cooling (20) the first gas phase in a controlled manner to knock out water or condensing water and optionally other condensates while keeping the fluid above a hydrate formation temperature thereof; separating off condensed liquids (6) and a second gas phase; wherein the second gas phase (8) has a water dew point which is lower than that of the initial multiphase hydrocarbon fluid stream. The invention also concerns a system for lowering the water dew point subsea.

Scrubbing CO2 from methane-containing gases using an aqueous stream

Fuel gas composition for use in cutting welding or hot working metals and glass

A gas composition containing about 1% to about 20% by volume of a normally gaseous aliphatic hydrocarbon and the balance being essentially hydrogen is suitable for use in cutting, welding or hot working of metals or glass.

A method and system for lowering the water dew point of a hydrocarbon fluid stream subsea

Method of de-acidification in which acid gases are produced in liquid phase

Methods, products & Uses relating thereto

A method of scavenging acid sulphide species (especially hydrogen sulphide) from an industrial or environmental material (e.g. crude oil, natural gas, produced water from a well, used fracturing fluids, used water-flooding fluids and drilling muds), the method comprising contacting the material with: (a) propenal (also known as acrolein) and/or maleimide and/or ethyl-2-chloroacetoacetate: and (b) a base, which could be an amino compound, a phosphorus compound, an inorganic base, a triazine etc.

Method for producing a fuel using renewable hydrogen

Integrated process and system for measurement and treatment of toxic gases in deep natural gas

An integrated process and system for measurement and treatment of toxic gases in deep natural gas. The process comprises: cooling and depressurizing deep natural gas and then drying same; sequentially performing radon, hydrogen sulfide, and mercury measurements on the dried deep natural gas; if it is found after the measurements that the concentrations of mercury, radon, and hydrogen sulfide in the deep natural gas reach standards, delivering the deep natural gas to a gas transmission pipeline; if it is found after the measurements that the concentrations of radon, hydrogen sulfide, and mercury in the deep natural gas are substandard, sequentially performing harmless treatment on radon and partial mercury, hydrogen sulfide, and remaining mercury in the deep natural gas; sequentially performing mercury, radon, and hydrogen sulfide measurements on the deep natural gas having experienced the harmless treatment; if the concentrations of mercury, radon, and hydrogen sulfide in the deep natural ...

Method of treating a hydrocarbon stream comprisingMethod of treating a hydrocarbon stream comprisingmethane, and an apparatus therefor methane, and an apparatus therefor

Method and apparatus for circulating a glycol stream, and method of producing a natural gas product stream

Gas-stream efficient cogeneration process and system based on biomass gasification and methanation

METHOD OF TREATING A HYDROCARBON STREAM COMPRISING METHANE, AND AN APPARATUS THEREFOR

METHOD AND APPARATUS FOR CIRCULATING A GLYCOL STREAM, AND METHOD OF PRODUCING A NATURAL GAS PRODUCT STREAM

Process for producing treated natural gas, A C3+ hydrocarbon-rich fraction and optionally an ethane-rich stream, and associated apparatus

Carboxylic acid salt removal during hydrate inhibitor recovery

PROCESSING BIOMASS

Processing biomas.

Method of scavenging hydrogen sulfide from hydrocarbon stream

The invention is related to hydrogen sulfide scavenging additive, capable of scavenging hydrogen sulfide in hydrocarbons by forming water soluble scavenged products which are capable of getting separated from hydrocarbon even at acidic pH without causing fouling and decomposition problems, consisting of aldehyde or aldehyde and polyethylene glycol [PEG], and wherein said aldehyde is glyoxylic acid. The invention is also related to a method of scavenging hydrogen sulfide employing present scavenging additive.

Method of treating an off-gas stream and an apparatus therefor

The present invention provides a method of treating an off-gas stream ( 80 ) comprising NH 3 and H 2 S to provide a sulphate stream ( 910 ), the method comprising the steps of: (i) providing a first off-gas stream ( 80 ) comprising NH 3 , H 2 S, CO 2 and optionally one or more of HCN, COS and CS 2 ; (ii) passing the first off-gas stream ( 80 ) to an incinerator ( 300 ) to oxidise NH 3 , H 2 S, and optionally one or more of HCN, COS and CS 2 to provide a second off-gas stream ( 310 ) comprising N 2 , H 2 O, SO 2 and CO 2 ; (iii) scrubbing the second off-gas stream ( 310 ) with a first aqueous alkaline stream ( 380, 876 a ) in a caustic scrubber ( 350 ) to separate SO 2 and a part of the CO 2 from the second off-gas stream to provide a spent caustic stream ( 360 ) comprising carbonate and one or both of sulphite and bisulphite and a caustic scrubber off-gas stream ( 370 ) comprising N 2 and CO 2 ; and (iv) passing the spent caustic stream ( 360 ) to an aerator ( 900 ) comprising sulphur-oxidising bacteria in the presence of oxygen to biologically disc sulphite and bisulphite to sulphate to provide a sulphate stream ( 910 ).

Tertiary Amine Salt Additives for Hydrate Control

New tertiary amine salts are useful as gas hydrate inhibitors in oil and gas production and transportation. These tertiary amine salts give very good separation from an emulsion, are economic and have reduced toxicity concerns.

Cryogenic system for removing acid gases from a hydrocarbon gas stream, with removal of hydrogen sulfide

A system for removing acid gases from a raw gas stream includes an acid gas removal system (AGRS) and a sulfurous components removal system (SCRS). The acid gas removal system receives a sour gas stream and separates it into an overhead gas stream comprised primarily of methane, and a bottom acid gas stream comprised primarily of carbon dioxide. The sulfurous components removal system is placed either upstream or downstream of the acid gas removal system. The SCRS receives a gas stream and generally separates the gas stream into a first fluid stream comprising hydrogen sulfide, and a second fluid stream comprising carbon dioxide. Where the SCRS is upstream of the AGRS, the second fluid stream also includes primarily methane. Where the SCRS is downstream of the AGRS, the second fluid stream is principally carbon dioxide. Various types of sulfurous components removal systems may be utilized.

Gas deacidizing method using an absorbent solution with cos removal through hydrolysis

The method deacidifies a gas including H 2 S and CO 2 . The gas is subjected to an absorption to collect the CO 2 and the H 2 S in an absorber, then to conversion through hydrolysis of the COS to H 2 S and CO 2 in a reactor, and to a second absorption to collect the H 2 S and the CO 2 formed in the reactor. The absorbent solution is regenerated in regenerator. The regenerated absorbent solution is separated into two which are: a main stream supplying the absorber, and a remaining stream supplying the second absorption

Method of removing acid compounds from a gaseous effluent with an absorbent solution based on i, ii/iii diamines

The invention relates to the removal of acid compounds from a gaseous effluent in an absorption method using an aqueous solution containing one or more diamines whose two amine functions are not connected to each other by rings and whose amine function in the α position is always tertiary and the amine function in the ω position is always either primary or secondary, more or less sterically hindered, and with have the general formula (I) as follows:

CHEMICAL LOOPING SYSTEM

A chemical looping system and a method of transferring oxygen therein are provided. The system has an air reactor adapted to receive air for oxidizing an oxygen carrier, a fuel reactor adapted to receive a fuel and the oxidized oxygen carrier for at least partially oxidizing the fuel by reducing the oxygen carrier to produce a gas. The oxygen carrier has oxide-dispersion-strengthened alloy particles. 115.-. (canceled)16. A chemical looping system , comprising:an air reactor adapted to receive air for oxidizing an oxygen carrier, anda fuel reactor adapted to receive a fuel and the oxidized oxygen carrier for at least partially oxidizing the fuel by reducing the oxygen carrier to produce a gas,wherein the oxygen carrier comprises oxide-dispersion-strengthened alloy particles.17. The chemical looping system according to claim 16 , wherein the oxide-dispersion-strengthened alloy particles are composed of a metal having a dispersion of a metal oxide or a carbide.18. The chemical looping system according to claim 17 , wherein the metal is selected from the group consisting of: nickel claim 17 , copper claim 17 , iron claim 17 , cobalt claim 17 , manganese claim 17 , and cadmium.19. The chemical looping system according to claim 17 , wherein the metal oxide is selected from the group consisting of: cerium oxide claim 17 , titanium oxide claim 17 , and zirconium oxide.20. The chemical looping system according to claim 17 , wherein the carbide is silicon carbide.21. The chemical looping system according to claim 17 , wherein the metal oxide or the carbide is doped.22. The chemical looping system according to claim 16 , wherein the fuel comprises a carbonaceous fuel.23. The chemical looping system according to claim 16 , wherein the fuel reactor is adapted to combust the fuel to produce the gas.24. The chemical looping system according to claim 16 , wherein the gas comprises COand HO.25. The chemical looping system according to claim 16 , wherein the fuel reactor is adapted ...

Expander and method for co2 separation

In one aspect an expander for separating carbon dioxide (CO 2 ) from a gas stream is presented. The expander includes (a) a housing; (b) at least one rotating component disposed within the housing; (c) at least one inlet disposed in the housing, wherein the inlet is configured to receive the gas stream;(d) at least one first outlet disposed in the housing, wherein the first outlet is configured to discharge a CO 2 rich stream; and (e) at least one second outlet disposed in the housing, wherein the second outlet is configured to discharge a CO 2 lean stream. The expander is configured to cool the gas stream such that a portion of CO 2 in the gas stream forms one or both of solid CO 2 and liquid CO 2 . The expander is further configured to separate at least a portion of one or both of solid CO 2 and liquid CO 2 from the gas stream to form the CO 2 rich stream and the CO 2 lean stream. System and method for separating carbon dioxide (CO 2 ) from a gas stream are also presented

IMIDO-ACID SALTS AND METHODS OF USE

Imido-acid salts and compositions containing imido-acid salts are described herein. Methods of their preparation and use are also described herein. The methods of using the imido-acid salts include the reduction of volatile compounds from gas and liquid streams and the delivery of pharmaceutical agents to subjects. 2. The compound of claim 1 , wherein L is substituted or unsubstituted Calkyl.3. The compound of claim 1 , wherein M is substituted or unsubstituted imidazolium or substituted or unsubstituted pyridinium.4. The compound of claim 1 , wherein Rand Rare combined to form substituted or unsubstituted aryl claim 1 , substituted or unsubstituted heteroaryl claim 1 , substituted or unsubstituted cycloalkyl claim 1 , substituted or unsubstituted cycloalkenyl claim 1 , substituted or unsubstituted cycloalkynyl claim 1 , substituted or unsubstituted heterocycloalkyl claim 1 , substituted or unsubstituted heterocycloalkenyl claim 1 , or substituted or unsubstituted heterocycloalkynyl.5. The compound of claim 1 , wherein Xis CO or SO.6. A composition comprising the compound of and a pharmaceutically acceptable carrier.10. The method of claim 9 , wherein the volatile compound is carbon dioxide claim 9 , sulfur dioxide claim 9 , or hydrogen sulfide.11. The method of claim 9 , wherein the system further comprises an amine.12. The method of claim 11 , wherein the amine is selected from the group consisting of primary amines claim 11 , secondary amines claim 11 , tertiary amines claim 11 , cyclic amines claim 11 , or mixtures thereof.14. The method of claim 13 , wherein the primary amine is selected from the group consisting of monoethanolamine claim 13 , diglycolamine claim 13 , 2-amino-2-methylpropanol claim 13 , or mixtures thereof.15. The method of claim 13 , wherein the secondary amine is selected from the group consisting of diethanolamine claim 13 , diisopropanolamine claim 13 , or mixtures thereof.16. The method of claim 13 , wherein the tertiary amine is N- ...

Process for separating co2 from a gaseous stream

Process for separating CO 2 from a gaseous stream by chemisorption to 1-ethyl-3-methylimidazolium (emim) or 1-propyl-3-methylimidazolium (pmim), characterized in that emim or pmim are present as carboxylate salt and that chemisorption is carried out in the presence of guanidinium acetate or 1-butyl-3-methylimidazolium (bmim) acetate.

System and method for separating components in a gas stream

An incoming compressed gas, such as natural gas, is pre-cooled and the gas separated from any included liquid. The pre-cooled and separated gas is expanded using an expander to rapidly reduce pressure and corresponding temperature, as well as remove any components solidified by the temperature drop. An output stream from the expander, combined with other streams, is again gas/liquid separated. The output separated gas stream is sent through another expansion and gas/liquid separation, separating one or more other components, such that a final output gas is achieved. In the case of natural gas, the final output is, for example, methane, which may be fed back to cool the incoming gas prior to end use of the methane.

Method and apparatus for sweetening and/or dehydrating a hydrocarbon gas, in particular a natural gas

A method for removing acidity and/or moisture from a hydrocarbon gas, in particular from a natural gas or a refinery gas fraction or a syngas, by absorption into a sweetening liquid and into a dehydration liquid, that are adapted to extract acid compounds or water from the gas, respectively. The method provides a step of prearranging a vertical elongated container ( 150 ) comprising at least one inner partition wall ( 168 ) that defines at least two treatment chambers within said container ( 151,152 ), a step of feeding a treatment liquid from the above into at least one of the two chambers ( 251,252 ) and feeding the gas to be treated from below into at least one same treatment chamber. It is also provided a step of selecting a treatment mode, wherein the gas flows along the two treatment chambers in a parallel or in a series arrangement, or one chamber being excluded; in particular the series-mode or the exclusion mode is actuated when the flowrate of the gas decreases below a minimum threshold value, while the parallel-mode is actuated when the flowrate of the gas rises above a maximum threshold value. An apparatus comprising at least such a container and a gas convey selective convey means ( 44′,44″ ), for actuating said treatment modes, in particular responsive to a flowrate of the gas. The apparatus and the method according to the invention allow to maintain the sweetening and/or dehydration efficiency, in particular in the case of a progressive reduction of the flowrate of natural gas that can be obtained from a well or gasfield.

Process for separating off acid gases from a water-comprising fluid stream

A process for separating off acid gases from a water-comprising fluid stream wherein the water-comprising fluid stream is contacted in an absorption zone with an absorbent, producing a deacidified fluid stream and an acid gas-loaded absorbent; the deacidified fluid stream is contacted in a scrubbing zone with an aqueous scrubbing liquid, producing a deaminated, deacidified fluid stream and an amine-loaded scrubbing liquid which is cooled, producing an absorber top condensate; the loaded absorbent is passed into a desorption zone producing a regenerated absorbent and desorbed acid gases; the regenerated absorbent is returned to the absorption zone in order to form an absorbent circuit, to which the amine-loaded scrubbing liquid and the absorber top condensate are introduced; and the desorbed acid gases are conducted through an enrichment zone and the acid gases exiting at the top of the enrichment zone are cooled, producing a desorber top condensate.

Process Design For Acid Gas Removal

A membrane permeation system and process accommodates varying acid gas inlet concentrations over time while utilizing only the initially installed equipment and still maintaining the non-permeate gas specification. The system and process provide flexibility to operate efficiently over a wide range of inlet CO 2 concentrations by adjustments to primary permeate, secondary permeate, and recycle gas operations. The glassy polymer membrane devices used in the system and process are selected so removal duty efficiency increases as acid gas concentration increase. Designing the system and process to handle about a 15% increase in acid gas concentrations over initial conditions effectively treats acid gas concentrations well above that 15% increase, thereby eliminating the need for additional equipment or for additional downstream amines and physical solvents.

Refining assemblies and refining methods for rich natural gas

Refining assemblies and methods for refining rich natural gas containing a first methane gas and other hydrocarbons that are heavier than methane gas are disclosed. In some embodiments, the assemblies may include a methane-producing assembly configured to receive at least one liquid-containing feed stream that includes water and rich natural gas and to produce an output stream therefrom by (a) converting at least a substantial portion of the other hydrocarbons of the rich natural gas with the water to a second methane gas, a lesser portion of the water, and other gases, and (b) allowing at least a substantial portion of the first methane gas from the rich natural gas to pass through the methane-producing assembly unconverted. The assemblies may additionally include a purification assembly configured to receive the output stream and to produce a methane-rich stream therefrom having a greater methane concentration than the output stream.

Heavy hydrocarbon removal from lean gas to lng liquefaction

A system for processing a gas stream can include a physical solvent unit, an acid gas removal unit upstream or downstream of the physical solvent unit, and an LNG liquefaction unit downstream of the acid gas removal unit. The physical solvent unit is configured to receive a feed gas, remove at least a portion of any C 5+ hydrocarbons in the feed gas stream using a physical solvent, and produce a cleaned gas stream comprising the feed gas stream with the portion of the C 5+ hydrocarbons removed. The acid gas removal unit is configured to receive the cleaned gas stream, remove at least a portion of any acid gases present in the cleaned gas stream, and produce a treated gas stream. The LNG liquefaction unit is configured to receive the treated gas stream and liquefy at least a portion of the hydrocarbons in the treated gas stream.

Adsorbents for removing contaminants from gas flows containing water

The invention relates to adsorbents for removing impurities from water-comprising gas streams, in particular for use in fuel cell systems, wherein the adsorbents comprise oxides of elements selected from the group consisting of Cu, Fe, Zn, Ni, Co, Mn, Mg, Ba, Zr, Ce, La or combinations of these elements, have a copper oxide content of at least 30% by weight and have pore volumes of less than 0.175 ml·g −1 for pores having a radius of less than 20 nm.

Method for separating components of a gas

A method is disclosed for separating components of a gas. A feed gas stream is cooled in the first vessel. The feed gas stream comprises methane, carbon dioxide, and a secondary component. A first portion of the secondary component condenses, desublimates, or a combination thereof to form a primary stream, resulting in a first depleted gas stream. The first depleted gas stream is cooled in a condensing exchanger such that a first portion of the methane condenses as a first liquid methane stream, resulting in a second depleted gas stream. The second depleted gas stream is cooled in the second vessel such that a first portion of the carbon dioxide desublimates to form a solid product stream, resulting in a third depleted gas stream.

Method of separating components of a gas

A method is disclosed for separating components of a gas. A feed gas stream is passed into a vessel. The feed gas stream includes methane, carbon dioxide, and water. The feed gas stream is cooled in the vessel such that a portion of the methane and a portion of the carbon dioxide condense and a portion of the water desublimates, resulting in a product stream and a depleted gas stream exiting the vessel.

Natural Gas Processing for Reduction in BTX Emissions and Energy Efficiency

An energy-efficient continuous process (and apparatus) that eliminates or reduces the emission of BTX into the environment during a process of dewatering natural gas using glycol. The apparatus includes an absorption tower to dewater the natural gas, and a glycol dewatering unit that includes a reboiler and a distillation column. Overhead vapor, including steam and BTX vapor, from the distillation column is condensed in an air-cooled heat exchanger. The liquefied BTX may be separated for fuel, sale or other disposal. A fan is positioned to force or induce air to flow through the air-cooled heat exchanger. The fan may be driven by a hydraulic motor by pressure of a glycol process stream. In another embodiment, the overhead vapors from the distillation column are cooled against a stream of water-containing glycol being charged to the glycol dewatering unit thereby preheating this stream and reducing energy input to the reboiler.

GAS PROCESSING SYSTEM AND METHOD FOR BLENDING WET WELL HEAD NATURAL GAS WITH COMPRESSED NATURAL GAS

A gas processing system and method for blending wet well head natural gas with compressed natural gas is provided. The system has two inlets in communication with a blending chamber. The blending chamber is preferably defined by a heat exchanger. One inlet receives an amount of raw wet well head natural gas therethrough. The second inlet receives an amount of processed and compressed natural gas therethrough. The two gases are mixed and sent to a downstream destination. 1. A method comprising the steps of:moving well head natural gas downstream from an in-ground well along a gas flow pathway through a mobile gas processing system, the mobile gas processing system removably positioned adjacent a well site location;moving processed and compressed natural gas (CNG) downstream from a processed CNG source through a portion of the gas processing system along the pathway;blending the well head natural gas with the CNG along the gas flow pathway to create a blended gas; andfeeding the blended gas to a downstream destination.2. The method of claim 1 , wherein the mobile gas processing system is mounted on a trailer removably positioned adjacent the well site location.3. The method of claim 2 , the step of blending further comprising the steps of:directing the well head natural gas into a blending chamber upstream from a heat exchanger;directing the CNG into the blending chamber; anddispersing each of the wet gas and the CNG in the blending chamber.4. The method of claim 3 , wherein the step of moving processed CNG downstream is accomplished by feeding CNG from an on-site source.5. The method of claim 4 , wherein the step of directing the well head natural gas into the blending chamber upstream from a heat exchanger is accomplished by moving the well head natural gas through a first inlet of blending chamber defining a portion of the pathway claim 4 , and wherein the well head natural gas is flowing from one of the following a filter claim 4 , a separator claim 4 , and a ...

METHOD AND SYSTEM FOR CONVERTING ASSOCIATED GAS

A volume of natural gas including a volume of methane and a volume of other alkanes may be cleaned of the other alkanes using a steam reformer system to create synthesis gas. 1. A gas conversion system to form a product gas from an associated gas stream , wherein the associated gas stream contains methane and non-methane hydrocarbons , the gas conversion system comprising:a steam generator capable of receiving system water and outputting steam;a mixing valve system capable of flow controlling at least a portion of the associated gas stream and the steam, and outputting a feed gas which is a mixture of the steam and the at least a portion of the associated gas stream;a super heater capable of receiving the feed gas and superheating the feed gas to a predetermined temperature range to form a superheated feed gas;a heavy hydrocarbon reactor containing a first catalyst having a leading edge and capable of receiving the superheated feed gas onto the leading edge and cracking a portion of non-methane hydrocarbons of the superheated feed gas into carbon oxides and hydrogen to form a heavy hydrocarbon reactor wet reformate comprising the associated gas stream methane, the carbon oxides, and the hydrogen; anda synthetic natural gas generator containing a second catalyst capable of receiving the heavy hydrocarbon reactor dry reformate to convert a portion of the carbon oxides and the hydrogen into converted methane to form a synthetic natural wet processed gas containing the associated gas stream methane and the converted methane, wherein the synthetic natural wet processed gas has an overall higher methane mole fraction than the associated gas stream.2. The gas conversion system according to claim 1 , wherein the heavy hydrocarbon reactor is an isothermal reactor.3. The gas conversion system according to claim 1 , wherein the heavy hydrocarbon reactor is an adiabatic reactor.4. The gas conversion system according to claim 1 , further comprising a carbon dioxide removal ...

Novel process for removal of nitrogen from natural gas

A method for removing nitrogen from natural gas includes contacting substantially dry natural gas that contains unwanted nitrogen with lithium metal. The nitrogen reacts with lithium to form lithium nitride, which is recovered for further processing, and pipeline quality natural gas. The natural gas may optionally contain other chemical species that may be reduced by lithium, such as carbon dioxide, hydrogen sulfide, and small amounts of water. These lithium reducible species may be removed from the natural gas concurrently with the removal of nitrogen. The lithium nitride is subjected to an electrochemical process to regenerate lithium metal. In an alternative embodiment, lithium nitride is reacted with sulfur to form lithium sulfide and nitrogen. The lithium sulfide is subjected to an electrochemical process to regenerate lithium metal and sulfur. The electrochemical processes are advantageously performed in an electrolytic cell containing a lithium ion selective membrane separator.

Cyclic amine for selectively removing hydrogen sulphide

The use of an amine of the formula (I) in which the R 1 to R 5 radicals are each as defined in the description, and an absorbent and a process for removing acidic gases from a fluid stream, especially for selectively removing hydrogen sulfide over carbon dioxide. The invention also relates to particular amines suitable for selective removal of hydrogen sulfide. Absorbents based on amines of the formula (I) have high selectivity, high loading capacity and good regeneration capacity.

Flexible adsorbents for low pressure drop gas separations

In various aspects, apparatuses and methods are provided for low pressure drop gas separations. In PSA processes, where there are large swings in pressure and corresponding swings in fluid velocity through the adsorbent, mechanical stresses during pressure cycling are of considerable concern. When that pressure is relieved in a lower pressure portion of the cycle, the high velocity of gas moving through the adsorbent bed can erode, strip away, or otherwise damage the channels within the adsorbent. Provided herein are methods which utilize flexible boundaries between adsorbent beds that are operated out of phase with one another. The flexible boundaries permit an increase in void space through the adsorbent during high pressure stages of the cycle and a decrease in void space through the adsorbent during low pressure stages of the cycle.

Process for removing co2 from crude natural gas

A method for treating a crude natural gas feed stream comprising methane and having a first carbon dioxide concentration, said method comprising the steps of: subjecting the crude natural gas feed stream to a separation process to provide: a purified natural gas stream having a second carbon dioxide content which is lower than the first carbon dioxide concentration in said crude natural gas stream; and, a carbon dioxide stream comprising carbon dioxide as the major component and methane; recovering the purified natural gas steam; optionally mixing the carbon dioxide stream with make-up methane and/or make-up air; passing the carbon dioxide stream and optional make-up methane or air through a heat exchanger to raise the temperature of the stream to the desired inlet temperature T 1 of an oxidation reactor; optionally mixing the carbon dioxide stream with make-up methane and/or make-up air; passing the heated stream from step (d) and any optional make-up methane and/or air to the oxidation reactor containing an oxidation catalyst, where the methane is oxidised; removing a gas stream including the products of the oxidation reaction from the reactor, said gas stream being at an outlet temperature T 2 which is higher than the inlet temperature T 1 ; passing the gas stream removed in step (g) through the heat exchanger against the carbon dioxide stream from step (a) to allow the heat to be recovered from the gas stream removed in step (g) and utilised to heat the carbon dioxide stream in step (d); and measuring the outlet temperature T 2 and controlling the inlet temperature T 1 by adjusting the amount of make-up methane and/or air added in step (c) and/or step (e).

Transport of Natural Gas Through solution in Liquid Hydrocarbon at Ambient Temperature

A method of transporting natural gas by liquefaction of natural gas at ambient temperature, achieved by mixing the natural gas at high pressure with a hydrocarbon that is a stable liquid at ambient temperature and ambient pressure. The hydrocarbon liquid may be crude oil or a distillate of crude oil. The method includes: liquefaction: mixing the natural gas with the hydrocarbon liquid at an ambient temperature and a high pressure to generate a liquid mixture, which contains the natural gas dissolved in the hydrocarbon liquid; shipping: transporting the liquid mixture using a marine tanker, during which the liquid mixture is maintained at ambient temperature and the high pressure; and regasification: at the destination, releasing a gas from the liquid mixture by lowering the pressure of the liquid mixture. The hydrocarbon liquid may be used multiple times. 1. A process of transporting natural gas , comprising:providing a hydrocarbon liquid, the hydrocarbon liquid being a stable liquid at ambient temperatures and ambient pressures;mixing the natural gas with the hydrocarbon liquid at an ambient temperature and a high pressure to generate a liquid mixture, the liquid mixture being a liquid containing the natural gas dissolved in the hydrocarbon liquid; andtransporting the liquid mixture using a marine tanker from a first location to a second location, during which the liquid mixture is maintained at ambient temperature and the high pressure.2. The process of claim 1 , wherein the hydrocarbon liquid is crude oil.3. The process of claim 1 , wherein the hydrocarbon liquid is a distillate of crude oil.4. The process of claim 1 , wherein the mixing step mixes more than 20 volumes of the natural gas into one volume of the hydrocarbon liquid.5. The process of claim 1 , wherein the high pressure is above 1000 psia.6. The process of claim 1 , further comprising: prior to the mixing step claim 1 , conditioning the natural gas claim 1 , including dehydration and hydrogen sulfide ...

Method of adsorptive gas separation using thermally conductive contactor structure

A method of adsorption allows separation of a first fluid component from a fluid mixture comprising at least the first fluid component in an adsorptive separation system having a parallel passage adsorbent contactor with parallel flow passages having cell walls which include an adsorbent material. The method provides for transferring heat from the heat of adsorption in a countercurrent direction along at least a portion of the contactor during adsorption and transferring heat in either axial direction along the contactor to provide at least a portion of the heat of desorption during a desorption step. A carbon dioxide separation process to separate carbon dioxide from flue gas also includes steps transferring heat from adsorption or for desorption along the parallel passage adsorbent contactor.

GAS TURBINE FUEL BLENDING USING INFERRED FUEL COMPOSITIONS

A system, method, and computer-readable medium for blending a fuel for use in a gas turbine are disclosed. A measurement of a heating value of a process gas and a measurement of a molecular weight of the process gas is obtained. An estimate of a composition of the process gas is obtained using the obtained measurement of the heating value and the obtained measurement of the molecular weight. A blending ratio of the process gas and a natural gas is selected based on the estimate of the composition of the process gas. The process gas and the natural gas are then blended according to the selected blending ratio to obtain a fuel mixture for use in the gas turbine. 1. A method of blending a fuel for use in a gas turbine , comprising:obtaining a measurement of a heating value of a process gas and a measurement of a molecular weight of the process gas;obtaining an estimate of a composition of the process gas using the obtained measurement of the heating value and the obtained measurement of the molecular weight;selecting a blending ratio of the process gas and a natural gas based on the estimate of the composition of the process gas; andblending the process gas and the natural gas according to the selected blending ratio to obtain a fuel mixture for use in the gas turbine.2. The method of claim 1 , further comprising obtaining the estimate of the composition of the process gas using a set of linear equations relating the composition of the process gas to the measurement of the heating value of the process gas and the measurement of the molecular weight of the process gas.3. The method of claim 2 , wherein the set of linear equations includes a set of five linear equations relating five unknown molar fractions representing component gases of the process gas.4. The method of claim 3 , wherein the set of linear equations further including at least one additional molar fraction representing an additional component gas of the process gas claim 3 , wherein the at least one ...

Gas treatment system using supersonic separators

A crude natural gas stream treatment system comprising a first supersonic separator and a second supersonic separator, wherein the first supersonic separator comprises a crude gas inlet, a dry gas outlet and a first liquid outlet; wherein the second supersonic separator comprises a dry gas inlet, a treated gas outlet and a second liquid gas outlet, and wherein the dry gas outlet is in fluid communication with the dry gas inlet is disclosed.

Apparatus and process to condition natural gas for transportation

A conditioning assembly to condition a flow of natural gas to reduce hydrate formation for transportation. The conditioning assembly includes a housing with an inlet for introducing a flow of natural gas and an outlet for delivering conditioned gas, wherein the housing is capable of containing natural gas at or above atmospheric pressure. The assembly also includes at least one tube and fin style heat exchanger contained within the housing configured to cool the flow of natural gas to a temperature below hydrate formation temperature and a collection arrangement to remove hydrates from the housing that form during cooling of the natural gas. Also disclosed is a method of conditioning natural gas, substantially corresponding to the assembly described above, wherein a constant flow of natural gas is conditioned by alternating the flow of natural gas between at least two heat exchangers configured in a parallel arrangement.

Methods of dissolving gas hydrates

A method of dissolving a gas hydrate in a pipeline includes introducing a gas hydrate dissolving solution into the pipeline and allowing the gas hydrate dissolving solution to at least partially dissolve the gas hydrate in the pipeline. The gas hydrate dissolving solution includes cesium formate, potassium formate, or both, and has a flash point of greater than 50° C.

NATURAL GAS CONDENSATES IN FUEL COMPOSITIONS

Compositions corresponding to marine diesel fuels, fuel oils, jet fuels, and/or blending components thereof are provided that include at least a portion of a natural gas condensate fraction. Natural gas condensate fractions derived from a natural gas condensate with sufficiently low API gravity can provide a source of low sulfur, low pour point blend stock for formation of marine diesel and/or fuel oil fractions. Natural gas condensate fractions can provide these advantages and/or other advantages without requiring prior hydroprocessing and/or cracking. 1. A residual fuel or fuel blending product , comprising 5 vol % to 60 vol % of a natural gas condensate distillate fraction and 40 vol % or more of a resid boiling range fraction , the residual fuel or fuel blending product comprising a density at 15° C. of 960 kg/mor less , a sulfur content of 30 ,000 wppm or less , a pour point of 0° C. or less , and a CCAI of 825 or less , the natural gas condensate distillate fraction comprising a density at 15° C. of 835 kg/mor less.2. The residual fuel or fuel blending product of claim 1 , wherein the residual fuel or fuel blending product comprises a pour point of −10° C. or less.3. The residual fuel or fuel blending product of claim 1 , wherein the residual fuel or fuel blending product comprises 5 vol % to 15 vol % of the natural gas condensate distillate fraction.4. The residual fuel or fuel blending product of claim 1 , wherein the residual fuel or fuel blending product comprises a density at 15° C. of 900 kg/mor less.5. The residual fuel or fuel blending product of claim 1 , a) wherein the natural gas condensate distillate fraction comprises a non-hydroprocessed fraction claim 1 , a non-cracked fraction claim 1 , or a combination thereof; b) wherein the natural gas condensate distillate fraction comprises a sulfur content of 1000 wppm or less; or c) a combination of a) and b).6. A method for forming a residual fuel or fuel blending product claim 1 , comprising blending 5 ...

RECYCLING GAS TO HEAT THE HYDRODESULPHURIZATION SECTION

In one aspect, the present invention provides a method for recycling natural gas during a reformer startup in a methanol plant. The method comprises recycling natural gas from a point before entry into the natural gas saturator where the natural gas is recycled until the natural gas reaches a desired temperature. 1. A method comprising:recycling natural gas during a reformer startup in a methanol plant,wherein the natural gas is recycled from a point before entry into a natural gas saturator,wherein the natural gas is recycled until the natural gas is heated to a desired temperature.2. (canceled)3. The method according to claim 1 , wherein the method further comprises the step of cooling the recycled natural gas by passing the recycled natural gas through a heat exchanger.4. (canceled)5. The method according to claim 1 , wherein the recycled natural gas is cooled to 20° C. to 60° C.6. (canceled)7. The method according to claim 1 , wherein the method does not comprise at least one of the following: a natural gas flare step and a partial oxidation step.8. (canceled)9. The method according to claim 1 , wherein the recycled natural gas consists essentially of natural gas.10. The method according to claim 1 , wherein the recycled natural gas comprises methane claim 1 , ethane claim 1 , ethylene claim 1 , or hydrogen or a combination thereof.11. The method according to claim 1 , wherein the recycled natural gas consists of natural gas.12. The method according to claim 1 , wherein the recycled natural gas does not comprise carbon monoxide or carbon dioxide claim 1 , or a combination thereof.13. The method according to claim 1 , wherein the recycled natural gas passes through a hydrodesulphurization section; and wherein the natural gas is recycled from a point after exiting from the hydrodesulphurization section.14. (canceled)15. The method according to claim 1 , wherein the natural gas is recycled from a point after exiting from a sulfur absorber.16. The method according ...

BIOGAS PURIFICATION SYSTEM AND METHODS OF USE THEREOF

The present disclosure relates to a biogas purification system and method for removal of sulfur and halogenated compounds and acidic reaction products from biogas. A contaminant removal module is supplied containing a catalytic oxidation catalyst comprising vanadium oxide (VO) on a metal oxide support where the catalyst oxidizes 85% or more of the sulfur and halogenated compounds. This may be followed by a contaminant removal module containing alkali impregnated carbon which removes 85% or more of the acidic reaction products. If siloxane impurities are present in the biogas, one may utilize a contaminant removal module containing alumina oxide. 1. A biogas purification system for removal of sulfur and halogenated compounds and acidic reaction products from biogas , the system comprising:{'sub': 2', '5, 'a contaminant removal module containing a catalytic oxidation catalyst comprising vanadium oxide (VO) on a metal oxide support where said catalyst oxidizes 85% or more of said sulfur and halogenated compounds;'}a contaminant removal module containing alkali impregnated carbon wherein the alkali comprises an ionic salt of an alkali metal or alkaline earth metal and is present at a level of 5-15% by weight wherein said contaminant removal module removes 85% or more of said acidic reaction products.2. The biogas purification system of wherein said biogas after oxidation of said sulfur and halogenated compounds and removal of said acidic reaction products is combusted producing heated exhaust gases and said exhaust gases are employed to heat any one of said contaminant removal modules.3. The biogas purification system of wherein said biogas claim 1 , after removal of said sulfur and halogenated compounds and said acidic compounds claim 1 , is treated for removal of carbon dioxide (CO) claim 1 , nitrogen or oxygen claim 1 , said removal resulting in recovery of a methane offgas wherein said methane is employed to heat any one of said contaminant removal modules.4. The ...

COMPOSITION AND USE THEREOF FOR THE REMOVAL OF ACID GASES FROM HYDROCARBON FLUID STREAMS

Disclosed is a solvent composition and use thereof for removal of one or more acid gas from a fluid stream comprising: i) a physical solvent, ii) an alkali metal organoborate, where Rand Rmay be the same or different and are independently an alkylene group comprising 2 to 6 carbons, Rand Rmay be the same or different and are independently H or a linear or branched alkyl group comprising from 1 to 18 carbons, and Z is an alkali metal ion; and iii) optionally an amine compound. 2. The solvent composition of wherein the physical solvent is a dimethyl ether of polyethylene glycol (DMPEG) claim 1 , propylene carbonate (PC) claim 1 , N-methyl-2-pyrrolidone (NMP) claim 1 , methanol (MeOH) claim 1 , blends of N-acetylmorpholine and N-formylmorpholine claim 1 , 1 claim 1 ,3-dimethyl-3 claim 1 ,4 claim 1 ,5 claim 1 ,6-tetrahydro-2(1H)-pyrimidinone (DMTP) claim 1 , methoxytriglycol (MTG) claim 1 , or blends thereof.4. The solvent composition of wherein the alkali metal organoborate is sodium ethylene glycol borate claim 1 , potassium ethylene glycol borate claim 1 , sodium diethylene glycol borate claim 1 , potassium diethylene glycol borate claim 1 , sodium 1 claim 1 ,2-propanediol borate claim 1 , potassium 1 claim 1 ,2-propanediol borate claim 1 , sodium 2 claim 1 ,3-butanediol borate claim 1 , potassium 2 claim 1 ,3-butanediol borate claim 1 , sodium 1 claim 1 ,4-butanediol borate claim 1 , potassium 1 claim 1 ,4-butanediol borate claim 1 , sodium 1 claim 1 ,2-hexanediol borate claim 1 , potassium 1 claim 1 ,2-hexanediol borate claim 1 , sodium triethylene glycol borate claim 1 , or mixtures thereof.5. The solvent composition of further comprising iii) an amino compound.6. The solvent composition of wherein iii) the amino compound is selected from monoethanolamine claim 5 , methylethanolamine claim 5 , monoisopropanolamine claim 5 , diisopropanolamine claim 5 , 2-hydroxyethylpiperazine claim 5 , piperazine claim 5 , 1-methylpiperazine claim 5 , 2-methylpiperazine claim 5 , ...

Process For The Treatment Of Liquefied Hydrocarbons Using 3-(Piperazine-1-YL)Propane-1,2-Diol Compounds

A method for treating liquefied hydrocarbons including acid gases to remove the acid gases while minimizing loss of amine species, the method comprising the step of contacting the liquefied hydrocarbons with an absorbent aqueous solution of a first amine compound, the first amine compound having the structure 2. The method of claim 1 , wherein said absorbent aqueous solution comprises from about 0.1 wt. % to 90 wt. % of said first amine compound and additionally comprises from about 1 wt. % to 90 wt. % of a second amine compound.3. The method of claim 1 , wherein said absorbent aqueous solution comprises from about 0.1 wt. % to 50 wt. % of said first amine compound and from about 5 wt. % to 50 wt. % of a second amine compound.4. The method of claim 1 , wherein Ris hydrogen.5. The method of claim 1 , wherein Rand Rare propane-2 claim 1 ,3-diol.6. The method of claim 1 , wherein said acid gases comprise one or more gas selected from the group consisting of CO claim 1 , HS claim 1 , a mercaptan compound claim 1 , COS claim 1 , CS claim 1 , and mixtures thereof.7. The method of claim 1 , wherein said aqueous solution comprises a second amine compound comprising a piperazine compound selected from the group consisting of piperazine claim 1 , 2-methylpiperazine claim 1 , 2-hydroxyethylpiperazine and mixtures thereof.8. The method of claim 1 , wherein said absorbant aqueous solution comprises a second amine compound comprising compound selected from the group consisting of triethanolamine claim 1 , diethanolamine claim 1 , methyldiethanolamine claim 1 , diisopropanolamine claim 1 , 2-amino-2-(hydroxymethyl)propane-1 claim 1 ,3-diol claim 1 , 2-methylamino-2-(hydroxymethyl)propane-1 claim 1 ,3-diol claim 1 , 2-dimethylamino-2-(hydroxymethyl)propane-1 claim 1 ,3-diol claim 1 , 3-(2-(hydroxyethyl)methylamino)propane-1 claim 1 ,2-diol claim 1 , 3-(methylamino)bis(propane-1 claim 1 ,2-diol) claim 1 , 3-(amino)tris(propane-1 claim 1 ,2-diol) claim 1 , 3-(methylamino)propane-1 ...

METHOD AND SYSTEM FOR PRODUCING A FUEL FROM BIOGAS

A method for producing a fuel includes transporting one or more pressure vessels containing pressurized biogas from a first location to a second location, and removing biogas from the one or more pressure vessels at the second location. The fuel production process is improved by controlling the decanting flow rate to provide a total decant time greater than 30-40 minutes, by actively heating biogas contained within the one or more pressure vessels, or some combination thereof. 2. The method according to claim 1 , wherein step (i) claim 1 , (ii) claim 1 , or (iii) is performed such that the temperature of the biogas within the pressure vessel system is greater than −25° C. when the pressure is between 6.2 MPa and 7.6 MPa.4. The method according to claim 1 , wherein step (a) comprises filling the pressure vessel system with the biogas to a pressure between 6.9 MPa and 13.8 MPa.5. The method according to claim 4 , wherein step (c) comprises step (i).6. The method according to claim 4 , wherein step (c) comprises step (ii).7. The method according to claim 4 , wherein step (c) comprises step (iii).8. The method according to claim 1 , wherein step (c) comprises step (i) or step (iii) claim 1 , andwherein step (i) comprises controlling the flow rate such that the total decant time is greater than one hour.9. The method according to claim 1 , wherein step (c) comprises (ii) or (iii) claim 1 , and wherein step (ii) comprises injecting warming gas into the pressure vessel system.10. The method according to claim 1 , wherein step (c) comprises (ii) or (iii) claim 1 , and wherein step (ii) comprises delivering heat at more than 350 kW.11. The method according claim 1 , wherein step (a) comprises filling the pressure vessel system with the biogas such that the biogas has a density greater than a design density of natural gas.12. The method according to claim 1 , wherein step (a) comprises filling the pressure vessel system with the biogas to a density greater than 200 kg/m.13. ...

Metal-Organic Framework Extrudates With High Packing Density And Tunable Pore Volume

The present invention relates to extruded shaped bodies containing at least one metal-organic framework (MOF), methods for their preparation and their use. 1. A method for preparing a shaped body containing a metal-organic framework material (MOF) comprising the steps of(a) mixing a composition comprising the MOF and at least one additive; and(b) extruding the composition into a shaped body,wherein the MOF is dried prior to step (a).2. The method of claim 1 , wherein the composition of step (a) is dried prior to step (b).3. The method of claim 2 , wherein the drying of the composition of step (a) prior to step (b) comprises spray-drying.4. The method of claim 1 , wherein the MOF in step (a) is applied in the form of spheres.5. The method of claim 1 , wherein the at least one additive comprises at least one binder that is selected from the group consisting of oxidic binders and partially organic binders claim 1 , preferred aluminum oxide claim 1 , silicon oxide claim 1 , clay claim 1 , cement claim 1 , and silicon-organic compounds.6. The method of claim 5 , wherein the amount of the at least one binder additive based on the total weight of the shaped body is from 1 to 80 wt.-%.7. The method of claim 1 , wherein the metal of the MOF is selected from the group consisting of Mg claim 1 , Zn claim 1 , Al or mixtures thereof.8. The method of claim 7 , wherein the metal of the MOF is Al.9. A method of claim 7 , wherein the MOF comprises aluminum and one or more of the organic compounds selected from fumarate claim 7 , trimesate claim 7 , 2-aminoterephthalic acid and 4 claim 7 ,4′ claim 7 ,4″-benzene-1 claim 7 ,3 claim 7 ,5-triyl-tribenzoate.10. An extruded shaped body comprising a metal-organic framework material (MOF) claim 7 , wherein the metal of the MOF is selected from the group consisting of Mg claim 7 , Zn claim 7 , Al or mixtures thereof.11. The extruded shaped body of claim 10 , wherein the metal of the MOF is Al.12. The extruded shaped body of claim 10 , wherein ...

Refining assemblies and refining methods for rich natural gas

Refining assemblies and methods for refining rich natural gas containing a first methane gas and other hydrocarbons that are heavier than methane gas are disclosed. In some embodiments, the assemblies may include a methane-producing assembly configured to receive at least one liquid-containing feed stream that includes water and rich natural gas and to produce an output stream therefrom by (a) converting at least a substantial portion of the other hydrocarbons of the rich natural gas with the water to a second methane gas, a lesser portion of the water, and other gases, and (b) allowing at least a substantial portion of the first methane gas from the rich natural gas to pass through the methane-producing assembly unconverted. The assemblies may additionally include a purification assembly configured to receive the output stream and to produce a methane-rich stream therefrom having a greater methane concentration than the output stream.

Process for purifying gaseous mixtures containing acidic gases

A process is disclosed for purifying a gaseous mixture containing acidic gases, such as a natural gas, including contacting the gaseous mixture with an absorbent solution including: from 35% to 45% by weight of at least one tertiary amine relative to the total weight of the absorbent solution; from 4% to 12% by weight of at least one activator relative to the total weight of the absorbent solution selected from the primary amines and the secondary amines, the total content of tertiary amine and activator being from 38% to 50% by weight relative to the total weight of the absorbent solution, and the total concentration of tertiary amine and activator being between 3.8 and 4.2 mol/L; from 17% to 25% by weight of at least one C 2 to C 4 thioalkanol relative to the total weight of the absorbent solution; and the remainder being water to reach 100% by weight.

Process for the high temperature selective absorption of hydrogen sulfide

A high temperature selective absorption process for treating a gas stream having concentrations of both hydrogen sulfide and carbon dioxide to yield a treated gas stream having a reduced hydrogen sulfide concentration. The high temperature selective absorption process uniquely utilizes a novel absorbent composition which enables the processing of the gas stream under difficult absorption conditions and provides for other features of the inventive absorption process.

Contaminant removal process

Disclosed is a process comprising: step a) contacting a feed stream comprising a contaminant with an absorbent stream in a counter-current flow to produce a contaminant depleted product stream depleted in the molar quantity of the contaminant relative to the molar quantity of said contaminant in the feed stream, and a contaminant enriched absorbent stream enriched in the molar quantity of the contaminant relative to the molar quantity of said contaminant in the absorbent stream; and step b) treating the contaminant enriched absorbent stream to form a gaseous stream comprising said contaminant and a regenerated absorbent stream lean in the molar quantity of said contaminant relative to the molar quantity of said contaminant in the contaminant enriched absorbent stream; herein said absorbent stream comprises at least 15 wt. % of at least one compound (A) of general formula (I) or a mixture (M) comprising at least one compound (B) of general formula (II) and at least one compound (C) of general formula (III).

NATURAL GAS VEHICLE POWERTRAIN WITH ONBOARD CATALYTIC REFORMER

Catalyst compositions and methods for use of such catalyst composition in the exhaust gas recycle stream of an internal combustion engine for reforming of a methane-containing fuel are provided. A reformer incorporating such a catalyst for use in an exhaust gas recycle portion of an internal combustion engine powertrain is described. A powertrain incorporating such a reformer, a method of increasing the octane rating of an exhaust gas recycle stream, and a method of operating an internal combustion engine for methane combustion are also described. 1. A method for reforming a fuel in an internal combustion engine , said method comprising:(a) providing an exhaust gas-containing mixture to an exhaust gas recycle reformer, the exhaust gas recycle reformer comprising a reformer inlet, a reformer outlet, and a hydrocarbon-reforming catalyst composition, the exhaust gas-containing mixture comprising engine exhaust gas and a first hydrocarbon-containing fuel, the hydrocarbon-containing fuel comprising at least about 50 mol % methane, and(b) converting under reforming conditions at least a portion of the exhaust gas-containing mixture in the presence of the hydrocarbon-reforming catalyst composition comprising at least about 0.1 wt % of a hydrocarbon-reforming metal catalyst supported on a mixed metal oxide support, the mixed metal oxide support comprising at least about 20 wt % of a mixture of lanthanum oxide and aluminum oxide and at least about 10 wt % of a mixture of cerium oxide and zirconium oxide.2. The method of claim 1 , wherein the mixture of lanthanum oxide and aluminum oxide comprises about 0.4 wt % to about 15 wt % of lanthanum oxide based on the combined weight of lanthanum oxide and aluminum oxide claim 1 , wherein the mixed metal oxide support consists essentially of the mixture of lanthanum oxide and aluminum oxide and the mixture of cerium oxide and zirconium oxide claim 1 , or a combination thereof.3. The method of claim 1 , further comprising combusting a ...

PROCESS FOR PRODUCING SYNGAS USING PLASMA GASIFIERS

A process for gasification of solid feed material to produce a syngas includes: providing a plasma heated carbonaceous bed in a bottom section of a reactor vessel; forming a bed of deposited feed material on top of the carbonaceous bed; reacting the feed material with hot gases rising from the bottom section; forming, in a middle section of the reactor vessel, a syngas mixture containing a varying quantity of unreacted particles of the feed material; allowing the syngas mixture to rise into a top section of the reactor vessel; and at least partially quenching, by injecting a quench fluid including water, steam, or a mixture thereof, in a second, upper part of the top section, at least some of the unreacted particles sufficiently to reduce the number of unreacted particles exiting the reactor vessel that are likely to be deposited on walls of external ductwork. 1. A process for gasification of solid feed material to produce a syngas comprising:providing a plasma heated carbonaceous bed in a bottom section of a reactor vessel;feeding feed material into the reactor vessel to form a bed of deposited feed material on top of the carbonaceous bed in the bottom section;reacting the feed material with hot gases rising from the bottom section;forming, in a middle section of the reactor vessel, a syngas mixture containing a varying quantity of unreacted particles of the feed material;allowing the syngas mixture to rise into a top section of the reactor vessel toward one or more syngas outlets;maintaining conditions in the vessel such that unreacted particles from the middle section are subjected to further reactions in a first, lower, part of the top section; andat least partially quenching, by injecting a quench fluid including water, steam, or a mixture thereof, in a second, upper part of the top section, at least some of the unreacted particles sufficiently to reduce the number of unreacted particles exiting the reactor vessel that are likely to be deposited on walls of ...

SYSTEM AND METHOD FOR PROCESSING GAS STREAMS

A system for processing a gas stream includes a gathering subsystem configured to collect the gas stream from a well-head and a gas conditioning subsystem for receiving the gas stream from the gathering subsystem and providing physical conditioning of the gas stream. The system includes one or more gas turbines configured to receive and combust a first flow of the conditioned gas stream from the gas conditioning subsystem and coupled with an electrical generator. The system includes one supplemental combustor configured to receive heated exhaust gases from the one or more gas turbines and a second flow of the conditioned gas stream from the gas conditioning subsystem, wherein the at least one supplemental combustor is configured to combust the second flow of the conditioned gas stream and the heated exhaust gases such that an exhaust gas stream flow from the at least one supplemental combustor meets emission regulation requirements. 1. A system for processing a gas stream , the system comprising:a gathering subsystem configured to collect the gas stream from a well-head;a gas conditioning subsystem configured to receive the gas stream from the gathering subsystem and provide physical conditioning of the gas stream;one or more gas turbines configured to receive and combust a first flow of the conditioned gas stream from the gas conditioning subsystem and coupled with an electrical generator; andat least one supplemental combustor configured to receive heated exhaust gases from the one or more gas turbines and a second flow of the conditioned gas stream from the gas conditioning subsystem, wherein the at least one supplemental combustor is configured to combust the second flow of the conditioned gas stream and the heated exhaust gases such that an exhaust gas stream flow from the at least one supplemental combustor meets emission regulation requirements.2. The system of claim 1 , wherein the physical conditioning of the gas stream by the gas conditioning subsystem ...

Carbon dioxide sequestration in natural gas pipelines

Disclosed are processes, apparatuses, and systems that can be used in natural gas pipelines to significantly reduce the CO2 emissions of the natural gas pipelines, by capturing combusted flue gas which is normally wasted and putting it back to the pipelines, which can also be monetized (e.g., carbon credits). One example process may include producing a captured CO2 stream from a combustion gas of a gas turbine in a natural gas pipeline, compressing the captured CO2 stream, and combining the compressed CO2 stream with natural gas transported in the natural gas pipeline.

SYSTEM, APPARATUS, AND METHOD FOR HYDROCARBON PROCESSING

A process for the separation of a natural gas stream is provided. The process includes receiving an effluent gas flow from a first fractionator operating at a first pressure, splitting the effluent gas flow into a first stream and a second stream, and passing the first stream through a heat exchanger thereby causing a phase change of at least a portion of the first stream from a gaseous state to a liquid state. The process includes inserting the first stream into an upper portion of a second fractionator operating at a second pressure. The second pressure is lower than the first pressure. The process includes inserting the second stream into a lower portion of the second fractionator, and diverting liquids from a lower portion of the second fractionator to the first fractionator. 1. A process for separating a natural gas stream , the process comprising:receiving an input stream into a first fractionator, wherein the input stream comprises natural gas, and operating the first fractionator to fractionate the input stream, thereby forming a product stream and a first vapor effluent stream;directing the first vapor effluent stream into a second fractionator;operating the second fractionator to form a first liquid stream and a second vapor effluent stream; anddirecting at least a portion of the first liquid stream into the first fractionator, wherein said at least a portion of the first liquid stream is fractionated as part of the input stream, and said product stream is formed.2. The process of claim 1 , further comprising claim 1 , prior to directing the first vapor effluent stream into the second fractionator claim 1 , cooling the first vapor effluent stream.3. The process of claim 1 , further comprising claim 1 , prior to directing the first vapor effluent stream into the second fractionator claim 1 , directing the first vapor effluent stream through a heat exchanger.49-. (canceled)10. The process of claim 1 , further comprising claim 1 , prior to directing the first ...

PROCESS FOR OBTAINING HIGHLY PURE METHANE FROM BIOGAS, AND PLANT FOR CARRYING OUT THE PROCESS

A process and a plant for obtaining highly pure methane from biogas where biogas coming from a fermenter is compressed and fed to at least one membrane unit having a selectively permeable membrane, which provides a product gas stream containing an elevated proportion of methane and a gas stream containing a reduced proportion of methane. A quality sensor may be arranged in the outlet line for the highly pure product gas. A vacuum pump, the capacity of which can be regulated, may be connected to the low-pressure side of one of the membrane units. It is controlled by a control unit which receives its input signal from the quality sensor in the outlet line, and if the proportion of methane measured by the quality sensor falls below a certain value, the capacity of the vacuum pump is regulated so that the pressure difference at the membrane increases.

Process for cryogenic fluid odorisation

The present invention relates to a process for odorizing a cryogenic fluid, comprising a step a) of continuously feeding an odorizing agent in liquid or gaseous form into a feed zone, said feeding being carried out at a temperature above the temperature of the cryogenic fluid and above the crystallization temperature of the odorizing agent, a step b) of feeding said odorizing agent in liquid or gaseous form from step a) into a buffer zone in which the liquid or gaseous odorizing agent is brought to a temperature of about the temperature of the cryogenic fluid, and a step c) of feeding said odorizing agent cooled in step b) into the contact zone, wherein said odorizing agent comes into contact with said cryogenic fluid to be odorized. The present invention also relates to an odorizing device for implementing said odorizing process.

Use of expansion machines in gas scrubbers

A method for operating a gas scrubber is disclosed in which components are removed from a crude gas by scrubbing with a chemical or physical scrubbing medium to obtain a pure gas present at elevated pressure which, after heating, is introduced into an expansion machine which after work-performing decompression the pure gas leaves at an exit temperature. The amount of heat supplied to the pure gas during heating thereof is deliberately altered to approximate the exit temperature thereof to a predetermined target value at all times.

Hydrogen cyanide production with treated natural gas as source or methane-containing feedstock

The present invention relates to an improved process for producing hydrogen cyanide. More particularly, the present invention relates to a commercially advantageous process for producing hydrogen cyanide at enhanced levels of productivity and yield while using natural gas comprising at least one C2+ hydrocarbon, carbon dioxide, and hydrogen sulfide. The natural gas is purified to be used as a source of methane-containing feedstock.

Helium purity adjustment in a membrane system

A multi-stage membrane system is provided to separate helium from a gas stream such as a natural gas stream. There are at least two permeate streams from a first membrane module. One of the permeate streams is compressed and sent to a second membrane module while one of the permeate streams bypasses the compressor. There are control means provided to determine the flow for these two permeate streams based on factors including the compressor capacity, the concentration of the target component in the combined permeate streams and the capacity of the second membrane module.

COMPACT HYDROCARBON WELLSTREAM PROCESSING

A system () for offshore hydrocarbon processing comprises a host () at surface level, a subsea processing plant (), and an umbilical () connecting the host and the subsea processing plant. The subsea processing plant is adapted to receive a multi-phase hydrocarbon stream () from a wellhead and to output at least a hydrocarbon gas-phase stream () satisfying a rich gas pipeline transportation specification to a pipeline. The umbilical provides a desiccant () for drying the hydrocarbon gas, as well as power and control (), from the host to the subsea processing plant. 1. A system for offshore hydrocarbon processing , comprising:a host at surface level;a subsea processing plant, the processing plant being adapted to receive an input hydrocarbon stream from a wellhead and to output a hydrocarbon gas stream, satisfying a rich gas pipeline transportation specification, to a pipeline; andan umbilical connecting the host and the subsea processing plant, the umbilical being adapted to provide a desiccant from the host to the subsea processing plant.2. A system according to claim 1 , wherein the subsea processing plant is adapted so as not to direct the hydrocarbon gas stream to the host.3. A system according to or claim 1 , wherein the subsea processing plant is adapted to supply the hydrocarbon gas stream to a rich gas pipeline without further processing.4. A system according to any preceding claim claim 1 , wherein the host is adapted to supply power to the subsea processing plant claim 1 , preferably via the umbilical.5. A system according to any preceding claim claim 1 , wherein the host is adapted to control operation of the subsea processing plant claim 1 , preferably via the umbilical.6. A system according to claim 5 , wherein the host is adapted to control the hydrocarbon dew point and the water dew point of the hydrocarbon gas stream output by the subsea processing plant.7. A system according to claim 5 , wherein the host is adapted to control the content of HS claim ...

GASIFICATION APPARATUS

A gasification apparatus that is capable of appropriately controlling a differential pressure variation between the interior of a pressure vessel and the interior of a gasification furnace, and of simplifying a structure, by providing: a pressure vessel which forms a hollow shape; a gasification furnace which forms a hollow shape, and which is positioned inside the pressure vessel with a space section therebetween; a heat exchanger positioned at the upper section of the gasification furnace; a gas nozzle which supplies seal gas to the lower section of the space section; a char-receiving section provided above the heat exchanger in the space section; a pressure equalizer of which one end communicates with the interior of the gasification furnace, and the other end opens into the char-receiving section; and a gas flow channel which passes vertically through a side section of the char-receiving section. 1. A gasification apparatus which combusts and gasifies fuel to produce gas fuel , the gasification apparatus comprising:a pressure vessel which forms a hollow shape;a gasification furnace which forms a hollow shape and which is positioned inside the pressure vessel with a space section therebetween;a heat exchanger which is positioned at an upper section of the gasification furnace;a gas supply unit which supplies corrosion-resistant gas to a lower section of the space section;a char-receiving section which is provided above the heat exchanger in the space section;a pressure equalizer of which one end communicates with the gasification furnace and the other end opens into the char-receiving section; anda gas flow channel which passes vertically through a side section of the char-receiving section.2. The gasification apparatus according to claim 1 ,wherein the pressure equalizer is positioned at the space section, one end of the pressure equalizer opens into a furnace wall extending in the vertical direction in the gasification furnace, and the other end of the pressure ...

Process for Increased Selectivity and Capacity for Hydrogen Sulfide Capture from Acid Gases

A process for selectively separating HS from a gas mixture which also comprises COis disclosed. A stream of the gas mixture is contacted with an absorbent solution comprising one or more amines, alkanolamines, hindered alkanolamines, capped alkanolamines, or mixtures thereof. The HS/COselectivity of the absorbent solution is preferably greater than about 4.0 for an acid gas loading [mol(CO+HS)/mol(amine)] between about 0.2 and about 0.6, and is achieved by reducing pH of the absorbent solution. 1. A method for increasing the selectivity of an absorption process for HS absorption from a gas mixture which also comprises CO , the absorption process having an absorbent solution comprising one or more amines , the method comprising reducing the pH of the absorbent solution.2. The method of claim 1 , wherein the pH reducing step comprises diluting the absorbent solution.3. The method of claim 2 , wherein the diluted absorbent solution is less than 36 wt %.4. The method of claim 2 , wherein the diluted absorbent solution is less than 30 wt %.5. The method of claim 1 , wherein the pH reducing step comprises adding an acid to the absorbent solution.6. The method of claim 3 , wherein the acid is selected from phosphoric acid and sulfuric acid.7. The method of claim 1 , wherein the one or more amines is selected from the group consisting of amines claim 1 , alkanolamines claim 1 , sterically hindered akanolamines claim 1 , and mixtures thereof.8. The method of claim 7 , wherein the sterically hindered alkanolamine is a capped alkanolamine.9. The method of claim 7 , wherein the amine is M3ETB.10. The method of claim 7 , wherein the amine is EETB.11. The method of claim 7 , wherein the amine is MDEA.12. The method of claim 1 , wherein the HS/COselectivity of the absorbent solution is greater than about 5.0 for an acid gas loading [mol(CO+HS)/mol(amine)] range between about 0.2 and about 0.55.13. The method of claim 1 , wherein the HS/COselectivity of the absorbent solution is ...

Methods for regeneration of an organosilica media

Methods for regenerating a bed or organosilica particles and producing a treated gaseous stream are described herein. A method for regenerating a bed of organosilica particles includes introducing a heated regenerate stream to a bed of organosilica particles comprising captured C 3+ hydrocarbons under conditions sufficient to remove at least a portion of the captured C 3+ hydrocarbons from the organosilica particles; and introducing a cooled regenerate gaseous stream to the heated bed of organosilica particles. The regenerated organosilica particles are used to treat additional gaseous streams.

Heat exchanger on a fossil fuel processing assembly

The fossil fuel processing apparatus of the present disclosure includes two pressure vessels, or two separators, above a single vessel footprint area in a vertically stacked configuration. The stacked configuration permits the processing of gas to occur in a space having less length and less width than that of two separators arranged tip-to-end or side-by-side, respectively. The first and second separators are configured to separate fuel from non-fuel in a footprint area of a single gas separator as the fuel moves from upstream to downstream through a gas processing system. Further, the gas processing apparatus of the present disclosure permits the two separators to fit in a housing compartment that is more easily transportable via tractor-trailer.

Re-liquefying method for stored liquid

Provided is a re-liquefying method for a stored liquid which has a simple structure or operation and excellent process efficiency. Since the method does not use separate refrigerant, the structure or operation in the re-liquefying method is significantly simplified. In addition, since a portion of a main stream is separated to form a cycle similar to a refrigerant cycle which cools the mainstream, the process efficiency of the re-liquefying method is significantly improved. The above Abstract is a more accurate literal translation of the abstract from the original priority application than the PCT abstract.

Method of marine transportation of unsweetened natural gas

Marine transportation of natural gas is disclosed, including: a) removing a free water stream and a condensate stream from the source of raw natural gas to produce a dew-pointed unsweetened natural gas stream at an offshore supply location; b) subjecting the dew-pointed unsweetened natural gas stream to a selected level of dehydration to produce a partially dehydrated unsweetened natural gas stream at the offshore supply location; and c) transporting at least a portion of the partially dehydrated unsweetened natural gas stream in a gas containment system onboard a gas carrier vessel from the offshore supply location as a feed source of natural gas to an acid gas removal facility or an LNG production facility located at an offloading location.

Novel beta-hydroxylated tertiary diamines, a process for their synthesis and their use for eliminating acid compounds a gaseous effluent

The compound according to the invention is for example N,N,N′,N′-(tetramethyl)-1,6-diamino-2,5-hexanediol or N,N,N′,N′-(tetramethyl)-1,8-diamino-2,7-octanediol. The invention also relates to the method for preparing them and to their use for removing acid compounds contained in a gaseous effluent.

GAS PROCESSING SYSTEM AND METHOD FOR BLENDING WET WELL HEAD NATURAL GAS WITH COMPRESSED NATURAL GAS

A gas processing system and method for blending wet well head natural gas with compressed natural gas is provided. The system has two inlets in communication with a blending chamber. The blending chamber is preferably defined by a heat exchanger. One inlet receives an amount of raw wet well head natural gas therethrough. The second inlet receives an amount of processed and compressed natural gas therethrough. The two gases are mixed and sent to a downstream destination. 1. A method comprising the steps of:moving wet well head natural gas downstream along a gas flow pathway through a mobile gas processing system, the mobile gas processing system positioned on a well site location;moving processed and compressed natural gas (CNG) downstream through a portion of the gas processing system along the pathway;blending the wet gas with the CNG along the pathway of the processing system creating a blended gas; andfeeding the blended gas to a downstream destination.2. The method of claim 1 , the step of blending further comprising the steps of:directing the wet gas into a blending chamber defined by a heat exchanger;directing the CNG into the blending chamber; anddispersing each of the wet gas and the CNG in the blending chamber.3. The method of claim 2 , wherein the step of dispersing further comprises:moving gas particles in the blending chamber by pedesis.4. The method of claim 1 , further comprising the steps of:positioning the downstream destination on the well site location.5. The method of claim 4 , further comprising the steps of:combusting the blended gas within an internal combustion engine at the downstream destination.6. The method of claim 1 , the step of blending further comprising the steps of:attaching a CNG source line to a first inlet formed in a heat exchanger;directing the CNG through the source line into a blending chamber defined by the heat exchangerattaching a wet gas pipeline to a second inlet formed in the heat exchanger; anddirecting the wet gas ...

Absorption agent and a method for selectively removing hydrogen sulphide

An absorbent for selective removal of hydrogen sulfide from a fluid stream comprising carbon dioxide and hydrogen sulfide, which comprises a) 10% to 70% by weight of at least one sterically hindered secondary amine having at least one ether group and/or at least one hydroxyl group in the molecule; b) at least one nonaqueous solvent having at least two functional groups selected from ether groups and hydroxyl groups in the molecule; and c) optionally a cosolvent; where the hydroxyl group density of the absorbent ρabs is in the range from 8.5 to 35 mol(OH)/kg. Also described is a process for selectively removing hydrogen sulfide from a fluid stream comprising carbon dioxide and hydrogen sulfide, wherein the fluid stream is contacted with the absorbent. The absorbent features good regeneration capacity and high cyclic acid gas capacity.

METHOD OF ADSORPTIVE GAS SEPARATION USING THERMALLY CONDUCTIVE CONTACTOR STRUCTURE

A method of adsorption allows separation of a first fluid component from a fluid mixture comprising at least the first fluid component in an adsorptive separation system having a parallel passage adsorbent contactor with parallel flow passages having cell walls which include an adsorbent material. The method provides for transferring heat from the heat of adsorption in a countercurrent direction along at least a portion of the contactor during adsorption and transferring heat in either axial direction along the contactor and/or a direction transverse to the axial direction, to provide at least a portion of the heat of desorption during a desorption step. A carbon dioxide separation process to separate carbon dioxide from flue gas also includes steps transferring heat from adsorption or for desorption along the parallel passage adsorbent contactor. 1. An adsorption method for separating a fluid mixture comprising at least first and second fluid components , the method comprising:(a) admitting said fluid mixture into a parallel passage adsorbent contactor comprising an inlet end, an outlet end, and an adsorbent material, to flow from said inlet end to said outlet end;(b) adsorbing at least a portion of said first fluid component on said adsorbent material, releasing a heat of adsorption, and causing a thermal front to flow towards said outlet end;(c) recovering a first product fluid depleted in said first fluid component relative to said fluid mixture from said outlet end of said parallel passage adsorbent contactor;(d) terminating admission of said fluid mixture into said inlet end of said parallel passage adsorbent contactor;(e) desorbing at least a portion of said first fluid component adsorbed on at least one said adsorbent material by heating said adsorbent material; and(f) recovering a desorbed second product fluid enriched in said first fluid component from at least one of said inlet end and said outlet end of said parallel passage adsorbent contactor.2. The ...

SYSTEM AND METHOD FOR LIQUEFYING PRODUCTION GAS FROM A GAS SOURCE

A system for liquefying production gas from a gas source containing a fluid having C1-C12 entrained gases includes a first phase separator for separating the C1-C12 gases from the fluid from the gas source. The first phase separator has an inlet in fluid communication with the gas source, a gas outlet and at least one alternative outlet. A first cryogenic liquefaction vessel has an inlet and an outlet. The inlet is in fluid communication with the gas outlet of the first phase separator. The first cryogenic liquefaction vessel cools the C1-C12 gases to liquefy the C3-C12 petroleum gases. A second phase separator is provided for separating the C3-C12 liquefied gases from the C1-C2 gases. The second phase separator has an inlet, a liquid outlet and a gas outlet. The inlet is in fluid communication with the outlet of the first cryogenic liquefaction vessel. At least one storage vessel is provided in fluid communication with the liquid outlet of the second phase separator for collection of the liquefied C3-C12 petroleum gases. 1. A method for liquefying production gas from a gas source , comprising the steps of:introducing a flow stream from the gas source into a first phase separator to separate the C1-C12 production gases from the flow stream;passing the gas through a first stage of cryogenic liquefaction, the first stage of cryogenic liquefaction cooling the gas to create a fluid containing liquefied C3-C12 petroleum gas and a gaseous C1-C2 natural gas;passing the fluid containing liquefied C3-C12 petroleum gas and the gaseous C1-C2 natural gas through a second phase separator to separate the liquefied C3-C12 petroleum gas from the gaseous C1-C2 natural gas;collecting the liquefied C3-C12 petroleum gas into at least one liquefied petroleum gas storage vessel.2. The method of claim 1 , further comprising the steps of passing the gaseous C1-C2 natural gas through a second stage of cryogenic liquefaction for liquefying the gaseous C1-C2 natural gas and collecting the ...

Natural gas refining apparatus

A natural-gas purification apparatus includes: a plurality of carbon-dioxide separation units that are arranged in series and separate carbon dioxide, through carbon-dioxide separation membranes, from natural gas pressurized by a compressor, cooled by a cooling unit to liquefy and separate a high-boiling-point hydrocarbon component, and heated by a heating unit; a gas supply pipe that is provided between the plurality of carbon-dioxide separation units through on-off valves and that supplies the natural gas; a compressor that is provided to the gas supply pipe; a cooling unit that liquefies and separates a high-boiling-point hydrocarbon component by cooling the natural gas pressurized by this compressor; and a heating unit that heats the natural gas after the separation of the high-boiling-point hydrocarbon component by this cooling unit.

METHOD AND SYSTEM FOR EXTRACTING STRANDED GAS FROM UNDERWATER ENVIRONMENTS, CONVERTING IT TO CLATHRATES, AND SAFELY TRANSPORTING IT FOR CONSUMPTION

The invention provides a method and system for extracting stranded gas (such as natural gas or hydrogen) or a mixture of oil and natural gas from a subterranean environment such as beneath the ocean floor and converting it into a solid hydrate such as a clathrate featuring a) extracting stranded gas (such as natural gas or hydrogen) or a mixture of oil and natural gas; b) optionally separating the natural gas from the mixture of oil and natural gas in a first tank or vessel; c) transporting the stranded gas to a second tank or vessel; d) introducing sea water into the second tank or vessel; e) mixing the stranded gas and water to form a clathrate hydrate/water slurry; f) removing excess water from the clathrate hydrate slurry to form a solid comprising a clathrate hydrate; and g) processing the solid comprising a clathrate hydrate into a transportable form; and h) optionally collecting the gas into a transportable vessel. 1. A method for extracting natural gas from a hydrocarbon reservoir of oil and gas in a subterranean environment comprising the steps of(a) optionally drilling a well into the ocean floor to extract hydrocarbons as a natural gas or oil and natural gas mixture;(b) extracting hydrocarbons as a natural gas or oil and natural gas mixture;(b) separating oil from the natural gas in a separator;(c) optionally transporting, pumping or piping the oil to the ocean surface;(d) cleaning the natural gas of debris;(e) transporting, pumping or piping the natural gas into a gas/clathrate hydrate processing facility;(f) transforming the natural gas so that it forms solid hydrates;(g) assembling the solid hydrates into a shipping container suitable for transporting the solid hydrates to the ocean surface.2. The method of further comprising h) emptying the shipping containers at the ocean surface into a larger transport carrier for transport to a destination for conversion back to natural gas.3. The method of further comprising h) transporting the shipping containers ...

RENEWABLE WET DESULFURIZATION PROCESS USING A SUSPENSION BED

Provided is a renewable wet desulfurization process using a suspension bed, comprising mixing the desulfurization slurry with a hydrogen sulfide containing gas to obtain a first mixture, and passing the first mixture into a suspension bed reactor from bottom to top, with controlling the first mixture to have a dwell time of 5-60 minutes in the suspension bed reactor to allow they contact and react sufficiently with each other; and subjecting a second mixture obtained from the reaction to gas liquid separation to produce a rich solution and a purified gas, subjecting the resulting rich solution to flash evaporation and then reacting with an oxygen-containing gas for carrying out regeneration. The process of the present invention may reduce the hydrogen sulfide content in the hydrogen sulfide containing gas from 2.4-140 g/Nmto 50 ppm or less, so that the desulfurization efficiency is 98% or more. The present invention can achieve regeneration of a spent desulfurizer with a regeneration efficiency as high as 65%-83%, and the barren solution obtained by the regeneration may be recycled for being used as the desulfurization slurry, without generating secondary pollution, which is very suitable for industrial promotion. 1. A renewable wet desulfurization process using a suspension bed , comprising the following steps:(1), mixing a desulfurizer with water uniformly to prepare a desulfurization slurry;(2), mixing the desulfurization slurry with a hydrogen sulfide containing gas to obtain a first mixture, and passing the first mixture into a suspension bed reactor from bottom to top, with controlling the first mixture to have a dwell time of 5-60 minutes in the suspension bed reactor to allow the desulfurization slurry to contact and react sufficiently with the hydrogen sulfide containing gas; and(3), discharging a second mixture from the top of the suspension bed reactor, and subjecting the second mixture to gas liquid separation to produce a rich solution;(4), subjecting ...

System and method for removing acid gas from a sour gas stream

Embodiments of methods and associate system for removing acid gas from a sour gas stream are provided. The method includes (1) passing the sour gas stream in a counter-flow arrangement with an encapsulated phase change material and a lean amine based sorbent liquid configured to absorb the acid gas from the sour gas stream in an absorber; (2) separating the rich amine based sorbent liquid and the encapsulated phase change material; (3) passing the rich amine based sorbent liquid to an amine regenerator wherein the rich amine based sorbent liquid is heated to release the absorbed sour gas and regenerate the lean amine based sorbent liquid; and (4) passing the encapsulated phase change material and the regenerated lean amine based sorbent liquid through a cooler to reduce the temperature of the encapsulated phase change material such that the phase change material in the encapsulated phase change material solidifies.

Method for the selective removal of hydrogen sulfide

An absorbent for selective removal of hydrogen sulfide from a fluid stream comprising carbon dioxide and hydrogen sulfide comprises a) an amine compound of the formula (I) in which X, R 1 to R 7 , x, y and z are as defined in the description; and b) a nonaqueous solvent; where the absorbent comprises less than 20% by weight of water. Also described is a process for selectively removing hydrogen sulfide from a fluid stream comprising carbon dioxide and hydrogen sulfide, wherein the fluid stream is contacted with the absorbent. The absorbent features high load capacity, high cyclic capacity, good regeneration capacity and low viscosity.

In-line pipe contactor

An in-line pipe contactor includes a first tubular having an outer surface and an inner surface. The inner surface defines a first flow path and the outer surface defines, in part, a second flow path. A second tubular is arranged radially outwardly of the first tubular. The second tubular includes an outer surface portion and an inner surface portion. The inner surface portion defines at least in part, the second flow path. A first end cap is mounted at the first end. The first end cap supports a first plurality of atomizers. At least one of the first plurality of atomizers is directed along the first flow path. A second end cap is mounted at the second end portion. The second end cap supports a second plurality of atomizers. At least one of the second plurality of atomizers is directed along the second flow path.

ADSORBED NATURAL GAS STORAGE FACILITY

A natural gas storage facility for reducing effects of diurnal demand on a natural gas source is disclosed. The natural gas storage facility includes a guard bed system that has a heavy natural gas component storage capacity and that is operable to remove impurities from introduced natural gas, to selectively separate the introduced natural gas into a heavy natural gas component and a light natural gas component, to retain the heavy natural gas component and to release the heavy natural gas component and an adsorption bed system that fluidly couples to the guard bed system, that has a light natural gas component storage capacity, that contains a light natural gas adsorbent that is a microporous material, and that is operable to retain the light natural gas component using the light natural gas adsorbent and to release the light natural gas component from the light natural gas adsorbent. 2. The natural gas storage facility of claim 1 , where the guard bed system contains a heavy natural gas adsorbent material that is operable to remove impurities from the introduced natural gas claim 1 , to selectively separate the introduced natural gas into the heavy natural gas component and the light natural gas component claim 1 , to retain the heavy natural gas component by adsorption claim 1 , and to release the heavy natural gas component by desorption.3. The natural gas storage facility of claim 2 , where the heavy natural gas adsorbent material is a microporous material.4. The natural gas storage facility of claim 1 , where the microporous material has a BET Specific Surface Area value of at least about 800 meters squared per gram (m/g) and a Micropore Volume value of at least about 0.300 centimeters cubed per gram (cm/g) of microporous material as determined using nitrogen porosimetry at 77° K.5. The natural gas storage facility of claim 1 , where the microporous material is an activated carbon with slit-shaped micropores claim 1 , has a bulk density is in a range of from ...

SYSTEM AND METHOD FOR BLENDING BIOGAS

A method and system for blending biogas with conventional fuel in which the fuel blend is automatically adjusted for lower biogas flows and methane concentrations by introducing higher concentrations of conventional fuels. The system is able to automatically adjust the fuel blend, thereby eliminating the requirement for manual intervention, and producing a variable blended biogas that can be utilized within existing natural-gas fired combustion units such as boilers, furnaces, heaters, etc., as well as enabling automatic adjustment and operation, maximum usage of biogas, and integration with combustion unit controls. Using all available biogas to provide energy also minimizes the need for flaring unused biogas. 1. A fuel blender for a combustion unit , comprising:a first inlet for receiving biogas;a second inlet for receiving fuel gas;a chamber for receiving and mixing the biogas and the fuel gas;a fuel control valve at each inlet for adjusting the relative amounts of the biogas and fuel gas entering the fuel chamber;an outlet extending from the fuel chamber wherein the mixed fuels exit the fuel blender for providing fuel to a remote combustion unit.2. The fuel blender of claim 1 , further comprising:a controller located at the combustion unit location for adjusting one or more of the control valves on the combustion unit for enabling the variable biogas blend to be utilized by the combustion unit.3. The fuel blender of claim 2 , wherein the controller includes a dynamic feedback system having real-time instruments for enabling the two-way communication between the blender and the combustion unit.4. The fuel blender of claim 3 , wherein the Wobbe Index values measured at the blender controller enable the combustion unit controls to adjust automatically to the variable biogas blend on a feed-forward basis.5. The fuel blender of claim 4 , wherein the Wobbe Index value is a calculated real-time value.6. The fuel blender of claim 1 , wherein the biogas is used as the ...

SYSTEMS AND METHODS FOR CONTROLLING, MONITORING, AND OPERATING REMOTE OIL AND GAS FIELD EQUIPMENT OVER A DATA NETWORK WITH APPLICATIONS TO RAW NATURAL GAS PROCESSING AND FLARE GAS CAPTURE

An intelligent controls system for a field-deployable system for producing dry natural gas (NG) and natural gas liquids (NGLs) from a raw gas stream is disclosed. The control system is used to ensure correct specifications of both dry NG (above a desired minimum methane number) and NGLs (below a desired maximum vapor pressure) from any supplied raw natural gas source by controlling three system parameters: inlet gas flow rate, system operating pressure, and separator-reboiler temperature set point. The input parameters include: heat content of the input gas stream, volume of the input gas stream, desired methane number of the NG, and desired vapor pressure of the NGLs. The controls system allows any piece of remote field equipment for performing complex chemical processing to be monitored, controlled, and operated remotely. A large array of distributed field equipment situated around the world can all be controlled primarily through a single interface provided in a central control center. 1. A non-transitory digital storage medium for storing executable program code , which when executed by a hardware processor , causes the hardware processor to perform a process of controlling separation of a raw natural gas stream into at least two useable streams comprising a dry natural gas stream (NG) having a desired minimum methane number and a natural gas liquids stream (NGLs) having a desired maximum vapor pressure , the program code causing the processor to perform steps comprising:controlling one or more process parameters, the one or more process parameters selected from the group consisting of an inlet flow rate of a raw natural gas stream, a system operating pressure, and a temperature setpoint of a separation subsystem,wherein the one or more process parameters are controlled to maintain the desired minimum methane number and the desired maximum vapor pressure.2. The non-transitory digital storage medium of claim 1 , wherein the inlet flow rate claim 1 , the system ...

PROCESS FOR NATURAL GAS PRODUCTION

Processes for natural gas production are described. The processes involve combining a membrane separation system and a thermal oxidizing system. The high and low hydrocarbon permeate streams from the membrane separation system are introduced into the thermal oxidizing system separately. The high hydrocarbon permeate stream provides fuel for the thermal oxidizing system, allowing a reduction in external fuel usage. The reduction in total fuel required yields increased gas production for the total plant. A solvent based acid gas removal system can optionally be included. 1. A process for natural gas purification comprising:passing a natural gas feed stream to a membrane separation system to separate the natural gas feed stream into a first permeate gas stream having a first hydrocarbon concentration, a second permeate gas stream having a second hydrocarbon concentration, the first concentration being higher than the second concentration, and a purified natural gas stream;introducing the first permeate gas stream into a thermal oxidizing system at a first position, the thermal oxidizing system comprising a combustion chamber with a fuel gas inlet, a combustion air inlet, two or more permeate stream inlets, and a burner positioned in the combustion chamber;introducing the second permeate gas stream to the thermal oxidizing unit at a second position; andrecovering the purified natural gas stream.2. The process of wherein the thermal oxidizing system uses less fuel gas than a thermal oxidizing unit in which a single permeate gas stream is introduced.3. The process of wherein the thermal oxidizing unit is smaller than a thermal oxidizing unit in which a single permeate gas stream is introduced.4. The process of wherein the membrane separation system includes two or more membrane separation units.5. The process of further comprising:removing acid gas from the purified natural gas stream using a solvent based acid gas removal process to form a purified natural gas product ...

Use of Aminals to Remove Acid Gases from Fluid Gas Streams

An aminal compound is injected into a fluid gas stream including at least one acid gas to reduce the amount of acid gas in the fluid gas stream. Having two reactive sites present in the aminal compound enables a much higher efficiency of acid gas capture than a simple alkanolamine, which isn't effective, for example, under dilute circumstances.

Liquefaction of associated gas at moderate conditions

A method is proposed for converting a portion of associated gas generated during crude oil production into a liquid form which permits the transport of a large amount of methane at moderate temperatures. A methane-containing liquid is produced at moderate temperature by: recovering the gas from oil production; drying the gas; chilling the dried gas; and separating the chilled gas into methane-rich and methane-lean streams.

Integrated Hydromethanation Fuel Cell Power Generation

The present invention relates to processes and apparatuses for generating electrical power from certain non-gaseous carbonaceous feedstocks through the integration of catalytic hydromethanation technology with fuel cell technology.

Device and method for separating a flowing medium mixture into fractions

The invention relates to a device for separating a flowing medium mixture into at least two fractions, comprising rotating means, means for physically increasing the difference in mass density of the fractions for separating, a feed for medium and a first outlet for discharging one of the fractions of the separated medium mixture. The invention also relates to a method for separating a flowing medium mixture.

Gas hydrate inhibitors

The technology described herein relates to anti-agglomerants suitable for use in preventing, inhibiting, or otherwise modifying the agglomeration of gas hydrates in crude hydrocarbon streams. The technology relates to anti-agglomerant additives, additive formulations, compositions containing such anti-agglomerant additives and additive formulations, and methods and processes of using such anti-agglomerant additives and additive formulations in preventing, inhibiting, or otherwise modifying agglomeration of gas hydrates.

Process and appratus for producing gas hydrate

A process is provided which includes: bringing a natural gas, e.g., methane gas or propane gas, or a mixture of these gases into gas-liquid contact with raw-material water to form a gas hydrate; compression-molding the gas hydrate into pellets; and cooling/depressurizing the pellets. Also provided is an apparatus for use in the process. In the cooling/depressurizing step 4, molded gas hydrate masses h 3 in a pressurized state are cooled and depressurized to a downstream-side pressure. In the cooling/depressurizing step 4, a receiving chamber 15 which accommodates the gas hydrate masses h 3 obtained in the molding step 3 is provided, and the masses h 3 are depressurized to the downstream-side pressure while passing through the receiving chamber 15 . The masses h 3 are introduced into and immersed in a liquid refrigerant r packed in the receiving chamber 15 so that the masses h 3 are cooled by solid/liquid contacting with the liquid refrigerant r.

Treating a crude and natural gas stream

A process for treating a crude and natural gas stream, which at least comprises the steps of: (a) passing a crude and natural gas stream (10) through an inlet (12) into a stabilization unit (14) to provide a stabilizer content (20); (b) passing an overhead gaseous stream (30) separated from the stabilizer content (20) through a first outlet (16); and (c) passing a bottom stream (40) comprising crude liquid hydrocarbons separated from the stabilizer content (20) and free water through a second outlet (18).

Method of desulfurization of town gas

A method of desulfurization of town gas is disclosed. The method of desulfurization of town gas of the invention is a method for desulfurizing town gas not containing hydrogen gas chracterized in that the desulfurization is carried out by adding hydrogen to the town gas, and by using copper-zinc desulfurizing agnet prepared by co-precipitation method. According to the invention, town gas desulfurized at high degree can be obtained stably for a long period of time.

Drying gas, comprises contacting gas containing water vapor with an ionic liquid, which absorbs the water vapor of gas

Drying gas, comprises: contacting gas containing water vapor with an ionic liquid, where the water vapor of the gas is absorbed by the ionic liquid.

LNG PROCESS FOR VARIABLE PIPELINE GAS COMPOSITION

The invention relates to a system, method and apparatus for processing natural gas in an LNG facility. A natural gas feed is introduced into a heavies removal unit. The heavies removal system includes a heavies removal column and a distillation column. The heavies removal column and the distillation column are connected via a purge/recovery line. One or more components of the natural gas feed is purged from the heavies removal column to the distillation column via the purge/recovery line to obtain a specified concentration or concentration range of heavy components feeding into the distillation column.

ABSORBENT SOLUTION CONTAINING THIADIAZOLE-DERIVED DEGRADATION INHIBITOR AND METHOD FOR LIMITING DEGRADATION OF ABSORBENT SOLUTION

Catalytic partial oxidation process for recovering sulfur from an H2S-containing gas stream

A process for purifying a light hydrocarbon stream containing H 2 S is disclosed in which the selective catalytic partial oxidation of the H 2 S component is carried out while the hydrocarbon components slip through substantially unconverted. A catalyst that favors the partial oxidation of H 2 S over conversion of the hydrocarbon component of a gaseous H 2 S-light hydrocarbon mixture is employed. Apparatus for selectively cleaning up light hydrocarbon streams containing low concentrations (e.g., less than 25 vol. %), and apparatus for selectively cleaning up light hydrocarbon streams having higher concentrations (e.g., greater than 25 vol. %) of H 2 S are also disclosed.

Method of production storage and transportation for gas hydrate

Pellet damaging is prevented at the time of pellet charging into a storage tank. There is provided a method of storing a gas hydrate in which pellets obtained by compression molding of powdery gas hydrate are conveyed into a storage tank by the use of a slurry liquor, which method includes pouring a liquid for impact absorption in advance into the storage tank so that the impact on the pellets charged in the storage tank is absorbed by the liquid for impact absorption.

Gas treating method and apparatus

A method and apparatus for treating natural gas comprises a contactor having a manifold for spreading gas in the contactor vessel, a plurality of perforated plates above the manifold, a spray system for spraying a treating liquid into an upwardly rising column of gas and a liquid level controller for maintaining the treating liquid above the perforated plates. Gas and liquid from the contactor pass through a cooler and are then separated. A treating liquid regeneration system receives the treating liquid and flashes the liquid at low pressure to separate hydrocarbon gases, hydrocarbon liquid and treating liquid. The treating liquid is regenerated by heating and flashing off contaminant gases and is ultimately redelivered to the contactor.

Gas treating method and apparatus

A method and apparatus for treating natural gas comprises a contactor having a manifold for spreading gas in the contactor vessel, a plurality of perforated plates above the manifold, a spray system for spraying a treating liquid into an upwardly rising column of gas and a liquid level controller for maintaining the treating liquid above the perforated plates. Gas and liquid from the contactor pass through a cooler and are then separated. A treating liquid regeneration system receives the treating liquid and flashes the liquid at low pressure to separate hydrocarbon gases, hydrocarbon liquid and treating liquid. The treating liquid is regenerated by heating and flashing off contaminant gases and is ultimately redelivered to the contactor.

Gas treating method and apparatus

A method and apparatus for treating natural gas comprises a contactor having a manifold for spreading gas in the contactor vessel, a plurality of perforated plates above the manifold, a spray system for spraying a treating liquid into an upwardly rising column of gas and a liquid level controller for maintaining the treating liquid above the perforated plates. Gas and liquid from the contactor pass through a cooler and are then separated. A treating liquid regeneration system receives the treating liquid and flashes the liquid at low pressure to separate hydrocarbon gases, hydrocarbon liquid and treating liquid. The treating liquid is regenerated by heating and flashing off contaminant gases and is ultimately redelivered to the contactor.

Method for treating contaminated gas

A method for treating natural gas using a vessel having a manifold for introducing gas in the vessel, a flow disperser above the manifold that prevents channeling of the gas, a spray system for spraying a treating liquid into an upwardly rising column of gas and, optionally, a liquid level controller for maintaining the level of a pool of treating liquid above the flow disperser.

Gas treating method and apparatus

A method and apparatus for treating natural gas comprises a contactor having a manifold for spreading gas in the contactor vessel, a plurality of perforated plates above the manifold, a spray system for spraying a treating liquid into an upwardly rising column of gas and a liquid level controller for maintaining the treating liquid above the perforated plates. Gas and liquid from the contactor pass through a cooler and are then separated. A treating liquid regeneration system receives the treating liquid and flashes the liquid at low pressure to separate hydrocarbon gases, hydrocarbon liquid and treating liquid. The treating liquid is regenerated by heating and flashing off contaminant gases and is ultimately redelivered to the contactor.

Gas Treating Method And Apparatus

A method and apparatus for treating natural gas comprises a contactor having a manifold for spreading gas in the contactor vessel, a plurality of perforated plates above the manifold, a spray system for spraying a treating liquid into an upwardly rising column of gas and a liquid level controller for maintaining the treating liquid above the perforated plates. Gas and liquid from the contactor pass through a cooler and are then separated. A treating liquid regeneration system receives the treating liquid and flashes the liquid at low pressure to separate hydrocarbon gases, hydrocarbon liquid and treating liquid. The treating liquid is regenerated by heating and flashing off contaminant gases and is ultimately redelivered to the contactor.

In-line device for gas-liquid contacting, and gas processing facility employing co-current contactors

Provided are gas processing facilities for the separation of components in a gas stream and methods of using the same. The facility includes one or more co-current contactors. Each contactor includes a mass transfer vessel having a mixing section. The mixing section receives a gas stream and a liquid contacting stream. The mixing section mixes theses two streams and releases a two-phase flow. Each contactor also includes a separator that receives the two-phase fluid stream from the mass transfer vessel in-line, and then separates a vapor phase from a liquid phase. The separator has a gas-phase outlet configured to release the vapor phase as a treated gas stream, and a liquid-phase outlet configured to release the liquid phase as a loaded treating solution. The contactors may be used to remove water or other contaminant from a natural gas stream or other gas stream.

Methane recovery from a landfill gas

A process is provided for recovering methane from landfill feed gas and other anaerobic digestors. The process comprising the following steps: firstly treating the feed gas to remove H 2 S; subsequently compressing the gas; and then treating the gas to remove further impurities. Additionally, there is provided a chiller for reducing the temperature of a gas flow. The chiller comprising: a shell arranged to be chilled, a plurality of bores through the shell and through which the gas flows, in use, and forming, together with the shell, a heat exchanger, a tangential inlet to each bore for creating a spiral flow of the gas through the bore, in use. Furthermore, a process is provided for purifying a gas feed using a reversible gas absorber unit comprising two hollow fibre gas/liquid contactors, each of which is arranged to provide a counter-current flow. The process comprising: setting up a partial pressure gradient in the first contactor using a reversible absorber capable of forming an adduct with the gas to be removed, introducing feed gas to the first contactor, forming an adduct of the gas to be absorbed, feeding the adduct to the second contactor, supplying a flushing counter-current flow to the second contactor to liberate the gas, and re-circulating the reversible absorber to the first contactor.

Process for producing a pressurized methane-rich liquid from a methane-rich gas

A process is disclosed for producing from a pressurized methane-rich gas stream a pressurized methane-rich liquid stream having a temperature above −112° C. (−170° F.) and having a pressure sufficient for the liquid to be at or below its bubble point. In this process, a methane-rich liquid stream having a temperature below about −155° C. (−247° F.) is supplied and its pressure is increased. A pressurized methane-rich gas to be liquefied is supplied and introduced to the pressurized methane-rich liquid stream at a rate that produces a methane-rich liquid stream having a temperature above −112° C. (−170° F.) and a pressure sufficient for the liquid to be at or below its bubble point.

Method of cooling a hydrocarbon stream and an apparatus therefor

A hydrocarbon feed stream is separated in one or more separators to provide a hydrocarbon stream and at least one methane-lean stream comprising a first ethane-rich header feed stream. The hydrocarbon stream is heat exchanged with at least one refrigerant stream to provide at least one cooled hydrocarbon stream and at least one at least partially evapourated refrigerant stream. The first ethane-rich header feed stream is passed to at least one fuel gas header, from which header fuel gas is removed as at least one fuel gas stream.

Liquid removal from natural gas

Methods have been developed for removing valuable liquid condensates from natural gas streams, which in certain embodiments do not use pumps and which are operated by the input pressure of gas to be processed. In other methods according to this invention pumps and equipment with moving parts are used. In one aspect a method described here includes: cooling input gas to a desired level to form a mist in the gas of condensed droplets of desired size, e.g., but not limited to, droplets of a largest dimension of at least 0.1 micrometer, 0.7 micrometer, or less than 1.0 micrometer; based on an analysis of the condensates, selecting a desired microfilter media to filter liquid condensates from the cooled gas; and filtering the cooled gas producing a liquid condensate(s) stream and a gas stream, each of which may be usable as fuel or in other methods or apparatuses. A gas collector has been developed to collect all or substantially all of the condensates from a gas sample, e.g. condensed hydrocarbons in a natural gas stream, for precise analysis and aid in filter media selection. A method and apparatus have been developed for analyzing a particular microporous filter media's filtration of condensates from a particular gas stream which employs collection of a liquids sample from inlet gas, from liquids produced by filtration, and from an outlet gas stream; the collected liquids are then analyzed and a suitable media is selected based on the analysis.

System and method for liquefying production gas from a gas source

A system for liquefying production gas from a gas source containing a fluid having C1-C12 entrained gases includes a first phase separator for separating the C1-C12 gases from the fluid from the gas source. The first phase separator has an inlet in fluid communication with the gas source, a gas outlet and at least one alternative outlet. A first cryogenic liquefaction vessel has an inlet and an outlet. The inlet is in fluid communication with the gas outlet of the first phase separator. The first cryogenic liquefaction vessel cools the C1-C12 gases to liquefy the C3-C12 petroleum gases. A second phase separator is provided for separating the C3-C12 liquefied gases from the C1-C2 gases. The second phase separator has an inlet, a liquid outlet and a gas outlet. The inlet is in fluid communication with the outlet of the first cryogenic liquefaction vessel. At least one storage vessel is provided in fluid communication with the liquid outlet of the second phase separator for collection of the liquefied C3-C12 petroleum gases.