СПОСОБ ПОЛУЧЕНИЯ БИОМЕТАНА ПУТЕМ ОЧИСТКИ БИОГАЗА ИЗ ХРАНИЛИЩ НЕОПАСНЫХ ОТХОДОВ И УСТАНОВКА ДЛЯ ОСУЩЕСТВЛЕНИЯ СПОСОБА

Изобретение относится к способу получения биометана путем очистки биогаза из хранилищ неопасных отходов (NHWSF) и к установке для осуществления такого способа. Способ получения биометана путем очистки биогаза из хранилищ неопасных отходов включает сжатие начального газового потока, введение потока газа, подлежащего очистке, по меньшей мере в один адсорбер, заполненный адсорбентами, способными к обратимой адсорбции VOC. Включает подвергание обедненного по VOC газового потока, выходящего из адсорбера, по меньшей мере одному этапу мембранного разделения с целью частичного отделения COи Oот газового потока. Далее следует введение ретентата, полученного на этапе мембранного разделения по меньшей мере в один адсорбер, заполненный адсорбентами, способными к обратимой адсорбции большей части оставшегося CO. Подвергание обедненного по COгазового потока, выходящего из адсорбера, заполненного адсорбентами, способными к обратимой адсорбции большей части оставшегося CO, этапу криогенного разделения ...

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 ...

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 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 – ...

ДЕЗОДОРИРУЮЩАЯ СЕРООЧИСТКА ПРИРОДНОГО ГАЗА ПОСРЕДСТВОМ МЕМБРАННОГО КОНТАКТНОГО АППАРАТА

СПОСОБ ПОЛУЧЕНИЯ МЕТАНА ИЗ БИОМАССЫ

... 1. Способ получения метана из биомассы, включающий следующие стадии:а) гидропиролиз биомассы в реакторном сосуде гидропиролиза, содержащем молекулярный водород и катализатор дезоксигенирования, при температуре гидропиролиза выше приблизительно 1000°F (538°C) и при давлении гидропиролиза в интервале от приблизительно 100 до приблизительно 600 фунт/кв.дюйм (690-4140 кПа) с получением одиночного выпускного потока продукта гидропиролиза, содержащего уголь и газ;b) отделение указанного угля от указанного продукта гидропиролиза с получением продукта гидропиролиза со сниженным содержанием угля;с) гидроконверсия указанного продукта гидропиролиза со сниженным содержанием угля в реакторном сосуде гидроконверсии с использованием катализатора гидроконверсии при температуре гидроконверсии выше приблизительно 800°F (427°C) и при давлении гидроконверсии в интервале от приблизительно 100 до приблизительно 600 фунт/кв.дюйм (690-4140 кПа) с получением продукта гидроконверсии;d) охлаждение и введение указанного ...

Verfahren zur Entfernung von Kohlendioxid aus Biogas mittels einer aminhaltigen Waschlösung und Regeneration der anfallenden beladenen Waschlösung

Verfahren zur Entfernung von Kohlendioxid aus Biogas mittels einer aminhaltigen Waschlösung mit Aktivatorzusatz und Regeneration der anfallenden beladenen Waschlösung, die im Kreislauf gefahren wird, dadurch gekennzeichnet, dassa) das zu reinigende Biogas vor der Absorption auf einen Taupunkt von unter 20 °C entfeuchtet und mit einer Temperatur von 30 bis 70 °C mindestens einer Absorptionsstufe zugeführt wird,b) zur Absorption von COaus Biogas eine Waschlösung mit einer Temperatur von 40 bis 70 °C und einem Sauerstoffgehalt von unter 0,5 mg/l eingesetzt wird undc) die beladene Waschlösung zur Austreibung von COmindestens in einer Regenerationsstufe einer Behandlung mittels eines Strippprozesses unter Verwendung von Luft als Strippmedium bei einer Temperatur von 95 °C bis 115 °C unterzogen wird, wobei eine gereinigte Waschlösung mit einer Restbeladung von unter 45 g CO/l und einem Gehalt an Sauerstoff von ≤ 0,5 mg/l erhalten wird.

Methanisierungsverfahren und Kraftwerk umfassend die CO2-Methanisierung aus Kraftwerksrauchgas

Bei einem Methanisierungsverfahren umfassend die Umwandlung von aus einem Kraftwerksrauchgas (15) eines mit einem kohlenstoffhaltigen Brennstoff (3), insbesondere eines mit einem kohlenstoffhaltigen Gas, befeuerten Kraftwerks (2, 2a) mit angeschlossenem Wasser/Dampf-Kreislauf (11) stammendem, insbesondere abgezweigtem oder gewonnenem, CO2, insbesondere CO2-Gas (8), in einer Methanisierungsanlage (7) zu Methan (CH4), soll eine Lösung geschaffen werden, die es ermöglicht, ein Kraftwerk und eine Methanisierungsanlage energetisch günstig miteinander zu koppeln. Dies wird dadurch erreicht, dass die bei der CO2Umwandlung zu Methan (CH4) in der Methanisierungsanlage (7) als Abwärme entstehende Wärmeenergie zumindest teilweise in mindestens einen Stoff- und/oder Wärmeenergiestrom (13, 14, 37) ausgekoppelt und dieser zumindest teilweise mindestens einem der Brennkammer (17) eines Dampferzeugers (18) des Kraftwerks (2, 2a) brennerseitig zuströmenden Medium und/oder dem Wasser/Dampf-Kreislauf (11) ...

Electrical energy generating system

Fluid separation membrane module assembly

Membrane contactor

Apparatus and method for sequestering a gas

Process

A method for treating a crude natural gas feed stream comprising methane (CH4) and a first carbon dioxide (CO2) concentration. The method comprises a number of steps including subjecting the crude natural gas feed stream to a separation process such as a membrane separator (61, Fig 6) to provide a purified natural gas stream (62, Fig 6) having a second carbon dioxide content which is lower than the first carbon dioxide concentration and a carbon dioxide stream (cds) comprising a major carbon dioxide component and methane. The method includes recovering the purified natural gas steam and passing the carbon dioxide stream (cds) through a heat exchanger 26 to raise the temperature of the stream to the desired inlet temperature of an oxidation reactor 28. The heated stream is passed to the oxidation reactor containing an oxidation catalyst, where the methane is oxidised. The products of the oxidation reaction are removed from the reactor as a gas stream being at an outlet temperature which ...

VERFAHREN ZUR ANREICHERUNG VON METHAN IN DEPONIEGAS UND BIOGAS

PROCEDURE FOR THE ENRICHMENT OF METHANE IN DUMP GAS AND FERMENTATION GAS

Verfahren und Anlage zur Behandlung von Verbrennungsabgas

Gezeigt wird ein Verfahren zur Behandlung von Verbrennungsabgas (9) enthaltend Kohlenmonoxid und Kohlendioxid. Um das nach der Reinigung entstehende Produktgas wieder einer Verbrennung oder einem Erdgasnetz zuführen zu können, wird vorgeschlagen, dass - in einem ersten Schritt ein Gemisch aus zumindest Kohlenmonoxid und Kohlendioxid als erstes Produktgas (11) aus dem Verbrennungsabgas (9) entfernt wird, und - in einem zweiten Schritt Kohlenmonoxid und/oder Kohlendioxid aus dem ersten Produktgas (11) unter Verwendung von Wasser zu einem zweiten Produktgas (12) enthaltend molekularen Wasserstoff und/oder Methan umgesetzt werden.

Verfahren und Anlage zur Behandlung von Verbrennungsabgas

Gezeigt wird ein Verfahren zur Behandlung von Verbrennungsabgas (9) enthaltend Kohlenmonoxid und Kohlendioxid. Um das nach der Reinigung entstehende Produktgas wieder einer Verbrennung oder einem Erdgasnetz zuführen zu können, wird vorgeschlagen, dass - in einem ersten Schritt ein Gemisch aus zumindest Kohlenmonoxid und Kohlendioxid als erstes Produktgas (11) aus dem Verbrennungsabgas (9) entfernt wird, und - in einem zweiten Schritt Kohlenmonoxid und/oder Kohlendioxid aus dem ersten Produktgas (11) unter Verwendung von Wasser zu einem zweiten Produktgas (12) enthaltend molekularen Wasserstoff und/oder Methan umgesetzt werden.

Process for separation of gases

The invention relates to a specific apparatus, more particularly a chain of gas separation membrane modules, for separation of gas mixtures into two fractions each of elevated purity.

Temperature swing adsorption process for the separation of target species from a gas mixture

A temperature swing adsorption process for the removal of a target species, such as an acid gas, from a gas mixture, such as a natural gas stream. Herein, a novel multi-step temperature swing/pressure swing adsorption is utilized to operate while maintaining very high purity levels of contaminant removal from a produc t stream. The present process is particularly effective and beneficial in removing contaminants such as C0 ...

Methods of removing contaminants from a hydrocarbon stream by swing adsorption and related apparatus and systems

A pressure swing adsorption process for removal of C02 from natural gas streams through a combination of a selective adsorbent material containing an effective amount of a non-adsorbent filler, adsorbent contactor design, and adsorption cycle design. The removal of contaminants from gas streams, preferably natural gas streams, using rapid-cycle swing adsorption processes, such as rapid-cycle pressure swing adsorption (RC-PSA). Separations at high pressure with high product recovery and/or high product purity are provided through a combination of judicious choices of adsorbent material, gas-solid contactor, system configuration, and cycle designs. For example, cycle designs that include steps of purge and staged blow-down as well as the inclusion of a mesopore filler in the adsorbent material significantly improves product (e.g., methane) recovery. An RC-PSA product with less than 10 ppm H2S can be produced from a natural gas feed stream that contains less than 1 mole percent H2S.

Gas purification process utilizing engineered small particle adsorbents

A gas separation process uses a structured particulate bed of adsorbent coated shapes/particles laid down in the bed in an ordered manner to simulate a monolith by providing longitudinally extensive gas passages by which the gas mixture to be separated can access the adsorbent material along the length of the particles. The particles can be laid down either directly in the bed or in locally structured packages/bundles which themselves are similarly oriented such that the bed particles behave similarly to a monolith but without at least some disadvantages. The adsorbent particles can be formed with a solid, non-porous core with the adsorbent formed as a thin, adherent coating on the exposed exterior surface. Particles may be formed as cylinders/hollow shapes to provide ready access to the adsorbent. The separation may be operated as a kinetic or equilibrium controlled process.

Pressure-temperature swing adsorption process

A pressure-temperature swing adsorption process for the removal of a target species, such as an acid gas, from a gas mixture, such as a natural gas stream. Herein, a novel multi-step temperature swing/pressure swing adsorption is utilized to operate while maintaining very high purity levels of contaminant removal from a product stream. The present process is particularly effective and beneficial in removing contaminants such as CO ...

Configurations and methods for gas condensate separation from high-pressure hydrocarbon mixtures

System and method for processing an input fuel gas and steam to produce carbon dioxide and an output fuel gas

A method and system for processing an input fuel gas and steam to produce separate CO and output fuel gas streams. The method comprises the steps of using a decarboniser segment for reacting at least a solid sorbent reacts with the fuel gas and steam to remove carbon from the input fuel gas and to produce the output fuel gas stream in an exhaust gas from the decarboniser; using a calciner segment for reacting the solid sorbent from the decarboniser segment therein to release the CO into the CO gas stream; wherein CO partial pressures and temperatures in the decarboniser and calciner segments respectively are controlled such that the temperature in the decarboniser segment is higher than the temperature in the calciner.

Process for capturing a heavy metal contained in a wet gas incorporating a heat pump for heating the gas introduced into a capturing body

The process for capturing at least one heavy metal, chosen from mercury and arsenic, contained in a wet gas comprising steam, comprises the following steps: a) the wet gas is heated (1001) by heat exchange with a compressed heat transfer fluid obtained in step e) so as to obtain a condensed heat transfer fluid and a gas heated to a temperature Tc, b) the heated gas obtained in step a) is brought into contact with a body for capturing said heavy metal (2000) in order to obtain a gas depleted in heavy metal, c) the cooled heat transfer fluid obtained in step a) is expanded (4000), d) the gas depleted in heavy metal is cooled (1003) by heat exchange with the heat transfer fluid produced in step c) so as to obtain a gas cooled to a temperature Tf, the heat transfer fluid being vaporized during step d), e) the vaporized heat transfer fluid obtained in step d) is compressed (3000) so as to obtain a compressed heat transfer fluid, the compressed heat transfer fluid being recycled to step a).

Subsea fluid processing system

It is described a subsea fluid processing system adapted to receive a wellstream flow (1A, 101A) comprising a pressure control device (2,112) adapted to regulate the pressure of the wellstream flow (1A, 101A), a gas-liquid separator unit (4,105) adapted to receive the wellstream flow (1A, 101A) downstream of the pressure control device (2,112) and provide a liquid stream (4A, 105A) and a gas stream (4B, 105B), a first membrane separator (5,106) adapted to receive the gas stream (4B, 105B) and provide a retentate stream (5B, 106A) and a permeate stream (5A, 106B), a compressor (6,110) adapted to receive the permeate stream (5A, 106B) and provide a compressed permeate stream (6A, 110A), a discharge cooler (7, 111) adapted to receive the compressed permeate stream (6A, 110A) and provide a cooled permeate stream (7A, 111A) for injection into a subsurface reservoir, whereby the cooled permeate stream (7A, 111A) has higher density than the compressed permeate stream (6A, 110A).

Floating liquefied natural gas pretreatment system

A pretreatment system and method for a floating liquid natural gas ("FLNG") facility are presented. The inlet natural gas stream (19) flows through a membrane system (30) to remove carbon dioxide and a heat exchanger (40), producing first and second cooled C0 ...

Inline Non-targeted Component Removal

Abstract An improved method for the removal of non-targeted components from a non-targeted component containing gas stream, the method comprising the steps of: v) contacting the non-targeted component containing gas stream with a liquid solvent stream; vi) passing the product of step i) through a phase separation step to produce both a non-targeted component containing solvent stream and a partially purified gas stream; vii) passing the partially purified gas stream product of step ii) through a mass transfer step to produce a wet gas product; and viii)passing the wet gas product of step iii) through a final phase separation step to produce a purified gas stream. Figure 1 ...

System for acid gas removal

A gas purification system (144) including a hydrogen sulfide (H2S) absorber (148), a carbon dioxide (CO 2) absorber (150), a flash tank (186), and a H2 S concentrator (204). The gas purification system (144) may also include a gas path (152) though the H2S absorber (148) prior to the CO 2 absorber (150), a first solvent path (160 and 172) sequentially through the CO2 absorber (150), the H2S absorber (148), and the H2 S concentrator (204), and a second solvent path (162 and 200) sequentially through the CO 2 absorber (150), the flash tank (186), and the H2 S concentrator (204), wherein the first and second solvent paths flow a common solvent.

Method of producing sulfur dioxide

A method of producing sulfur dioxide is provided. A feed gas stream comprising at least 5% by volume hydrogen sulfide is provided. The feed gas stream is separated into a hydrogen sulfide stream and a hydrocarbon gas stream. An oxidant stream is provided and is combusted with the hydrogen sulfide stream to produce thermal power and a combustion stream containing sulfur dioxide and steam. Sulfur dioxide is separated from the combustion stream.

Zeolite adsorbents having a high external surface area and uses thereof

The present invention concerns the use, for gas separation, of at least one zeolite adsorbent material comprising at least one FAU zeolite, said adsorbent having an external surface area greater than 20 m ...

Regenerating sieve material used for processing natural gas

A system and process for regenerating sieve materials in a gas processing system. The process can include circulating a cooling gas through sieve material of a first bed, the cooling gas having a first concentration of carbon dioxide (C02) suitable for liquefaction into a liquid natural gas (LNG) product. The process can also include circulating a regenerating gas through sieve material of a second bed, the regenerating gas having a second concentration of carbon dioxide (C02) that is greater than the first concentration of carbon dioxide (C02) of the cooling gas.

Carbon molecular sieve membranes for aggressive gas separations

The present disclosure describes a process for separating at least a first gas component and a second gas component by contacting a gas stream comprising the first and second gas components with a carbon molecular sieve (CMS) membrane under aggressive gas separation conditions in which the partial pressure of the selectively sorbed gas component in the gas stream is high. Despite the high partial pressure of the sorbed gas component, the selectivity of the carbon molecular sieve membrane is not substantially reduced by plasticization or saturation. In some embodiments, the aggressive gas separation process may include contacting a gas stream at supercritical conditions with a CMS membrane to separate at least first and second gas components. The process may be useful for, among other things, the separation of CO2 from a natural gas stream.

METHOD AND SYSTEM FOR BIOMASS HYDROGASIFICATION

The present invention provides a system and method for producing hydrocarbons from biomass. The method is particularly useful for producing substitute natural gas from forestry residues. Certain disclosed embodiments convert a biomass feedstock into a product hydrocarbon by fast pyrolysis, and conversion of the resulting pyrolysis gas to the product hydrocarbon and carbon dioxide in the presence of hydrogen and steam while simultaneously generating the required hydrogen by reaction with steam under prescribed conditions for self-sufficiency of hydrogen. Methane is a preferred hydrocarbon product. A system also is disclosed for cycling the catalyst between steam reforming, methanation and regeneration zones.

CHARACTERISTICS OF TUNABLE ADSORBENTS FOR RATE SELECTIVE SEPARATION OF NITROGEN FROM METHANE

The present invention generally relates to a pressure swing adsorption process for separating an adsorbate impurity from a feed stream comprising product gas, said process comprising feeding the feed stream to an adsorbent bed at a pressure of from about 60 psig to 2000 psig, wherein said adsorbent bed comprises adsorbent having: An isosteric heat of adsorption of from about 5kJ/mol to about 30kJ /mol, as determined by the LRC method, for the adsorbate, and an equivalent 65kJ/mol or less isosteric heat of adsorption for the product, wherein the adsorbent has a rate of adsorption for the adsorbate impurity that is at least 10 times greater than the rate of adsorption for the product gas as determined by the TGA method and recovering said product gas with a reduced a level of said adsorbate impurity. The invention also related to an adsorbent useful in PSA separations, particularly separating N2 from methane, CO2 from methane O2 from N2 and the like.

CHARACTERISTICS OF TUNABLE ADSORBENTS FOR RATE SELECTIVE SEPARATION OF NITROGEN FROM METHANE

The present invention generally relates to a process that utilizes tunable zeolite adsorbents in order to reduce the bed size for nitrogen removal from a methane (or a larger molecule) containing stream. The adsorbents are characterized by the rate of adsorption of nitrogen and methane and the result is a bed size that is up to an order of magnitude smaller with these characteristics (in which the rate selectivity is generally 30) than the corresponding bed size for the original tunable zeolite adsorbent that has a rate selectivity of >100x.

METHOD AND APPARATUS FOR RECOVERING ABSORBING AGENTS IN ACID GAS TREATMENT

A method and apparatus for continuously treating acid gases including recovering absorbent chemicals by introducing streams leaving a regenerator and/or leaving an absorber into a static mixing zone wherein supplemental washing water is added to recover absorbent chemicals. Improvements to the prior art methods are provided where one or more absorbent chemical recovery units are included to increase the amount of recovered absorbent chemicals exiting the regenerator and/or exiting the absorber are increased and/or maximized. Absorbent chemical recovery units can include mixing units where liquid is added to the stream of sour gas and absorbent chemical to mix with and absorb the absorbent chemical from the stream.

TRANSPORT MEMBRANES FOR OLEFIN/PARAFFIN SEPARATIONS

The invention provides a high permeance and high selectivity facilitated transport membrane comprising a very small pore, nanoporous polyethersulfone (PES)/polyvinylpyrrolidone (PVP) blend support membrane, a hydrophilic polymer inside the very small nanopores on the skin layer surface of the support membrane, a thin, nonporous, hydrophilic polymer layer coated on the surface of the support membrane, and metal salts incorporated in the hydrophilic polymer layer coated on the surface of the support membrane and the hydrophilic polymer inside the very small nanopores, a method of making this membrane, and the use of this membrane for olefin/paraffin separations, particularly for propylene/propane and ethylene/ethane separations.

COMPOSITE BODY

The present invention provides a composite body having, on a porous substrate and in the interstices of the substrate that includes fibres, preferably of an electrically nonconductive material, a porous layer (1) composed of oxide particles bonded to one another and partly to the substrate that include at least one oxide selected from oxides of the elements Al, Zr, Ti and Si, preferably selected from Al2O3, ZrO2, TiO2 and SiO2, and having, at least on one side, a further porous layer (2) including oxide particles bonded to one another and partly to layer (1) that include at least one oxide selected from oxides of the elements Al, Zr, Ti and Si, preferably selected from Al2O3, ZrO2, TiO2 and SiO2, where the oxide particles present in layer (1) have a greater median particle size than the oxide particles present in layer (2), which is characterized in that the median particle size (d50) of the oxide particles in layer (1) is from 0.5 to 4 pm and the median particle size (d50) of the oxide ...

PROCESS FOR PURIFYING GASEOUS MIXTURES CONTAINING MERCAPTANS AND OTHER ACIDIC GASES

The invention relates to a process for purifying a gaseous mixture containing mercaptans and other acidic gases that comprises a step of contacting the said gaseous mixture with an absorbent solution comprising an alkanolamine, a C2-C4 thioalkanol and water.

METHODS OF REMOVING CONTAMINANTS FROM A HYDROCARBON STREAM BY SWING ADSORPTION AND RELATED APPARATUS AND SYSTEMS

A pressure swing adsorption process for removal of CO2 from natural gas streams through a combination of a selective adsorbent material containing an effective amount of a non-adsorbent filler, adsorbent contactor design, and adsorption cycle design.

METHOD AND SYSTEM FOR TREATING A FLOW BACK FLUID EXITING A WELL SITE

The present invention relates to a method and system for treating a flow back fluid (10) exiting a well site following stimulation of a subterranean formation. More specifically, the invention relates to processing the flow back fluid, and separating (200) into a carbon dioxide rich stream (20) and a carbon dioxide depleted stream (22), and continuing the separation until the carbon dioxide concentration in the flow back stream until the carbon dioxide concentration in the flow back gas diminishes to a point selected in a range of about 50-80 mol% in carbon dioxide concentration, after which the lower concentration carbon dioxide flow back stream continues to be separated into a carbon dioxide rich stream which is routed to waste or flare (94), and a hydrocarbon rich stream (16, 28) is formed.

SEPARATING CARBON DIOXIDE AND HYDROGEN SULFIDE FROM A NATURAL GAS STREAM USING CO-CURRENT CONTACTING SYSTEMS

... ²Systems and methods for separating CO2 and H2S from a natural gas stream are ²provided herein. The system includes a first loop of co-current contacting ²systems configured ²to remove H2S and CO2 from a natural gas stream and a second loop of co-²current contacting ²systems configured to remove the H2S from the CO2.² ...

PROCESS FOR SEPARATION AND PURIFICATION OF RENEWABLE PROPANE

A method for treating a gas stream comprising hydrogen and propane, where a combination of membrane separation and elevated pressure distillation is used to separate the hydrogen gas from the propane gas.

PROCESS FOR SEPARATION AND PURIFICATION OF RENEWABLE PROPANE

A method for treating a gas stream comprising hydrogen and propane, where a combination of membrane separation and elevated pressure distillation is used to separate the hydrogen gas from the propane gas.

SWING ADSORPTION PROCESSES UTILIZING CONTROLLED ADSORPTION FRONTS

A process for reducing the loss of valuable products by improving the overall recovery of a contaminant gas component in swing adsorption processes. The present invention utilizes at least two adsorption beds, in series, with separately controlled cycles to control the adsorption front and optionally to maximize the overall capacity of a swing adsorption process and to improve overall recovery a contaminant gas component from a feed gas mixture.

ABSORPTION MEDIUM AND METHOD FOR ABSORPTION OF AN ACID GAS FROM A GAS MIXTURE

An absorption medium which comprises water, an amine (A) of the formula (I), where R is a n-alkyl radical having 1 to 4 carbon atoms, and an alkanolamine (B) which is a tertiary amine or a sterically hindered primary or secondary amine, has a high absorption capacity for CO2 at a high absorption rate. Using the absorption medium, during the absorption of acid gases from a gas mixture, even without addition of a solvent, a separation of the absorption medium into two liquid phases or the precipitation of a solid during the absorption of CO2 and the regeneration of the absorption medium may be avoided.

ABSORPTION MEDIUM AND METHOD FOR ABSORPTION OF AN ACID GAS FROM A GAS MIXTURE

An absorption medium which comprises water, an amine (A) of formula (I) (see formula I) in which R is an n-alkyl radical having 1 to 4 carbon atoms, and an alkanolamine (B) which is a tertiary amine or a sterically hindered primary or secondary amine has a high absorption capacity for CO2 with a high absorption rate. In the absorption of acid gases from a gas mixture a separation of the absorption medium into two liquid phases or the precipitation of a solid upon absorption of CO2 and regeneration of the absorption medium can be avoided with the absorption medium, even without addition of a solvent.

METHODS OF REMOVING CONTAMINANTS FROM A HYDROCARBON STREAM BY SWING ADSORPTION AND RELATED APPARATUS AND SYSTEMS

A pressure swing adsorption process for removal of C02 from natural gas streams through a combination of a selective adsorbent material containing an effective amount of a non-adsorbent filler, adsorbent contactor design, and adsorption cycle design. The removal of contaminants from gas streams, preferably natural gas streams, using rapid-cycle swing adsorption processes, such as rapid-cycle pressure swing adsorption (RC-PSA). Separations at high pressure with high product recovery and/or high product purity are provided through a combination of judicious choices of adsorbent material, gas-solid contactor, system configuration, and cycle designs. For example, cycle designs that include steps of purge and staged blow-down as well as the inclusion of a mesopore filler in the adsorbent material significantly improves product (e.g., methane) recovery. An RC-PSA product with less than 10 ppm H2S can be produced from a natural gas feed stream that contains less than 1 mole percent H2S.

PROCESS FOR DEEP CONTAMINENT REMOVAL OF GAS STREAMS

A process for removing sulfur-containing contaminants from a gas stream, the process comprising the steps of: (a) providing a gas stream comprising natural gas, hydrogen sulfide, organic sulfur compounds and carbon dioxide to a first absorption unit, resulting in a hydrogen sulfide lean gas stream and a hydrogen sulfide rich absorbent; (b) providing the hydrogen sulfide lean gas stream to a second absorption unit, resulting in a cleaned gas stream and an absorbent rich in organic sulfur compounds and in carbon dioxide; (c) providing a first regenerator with the hydrogen sulfide rich absorbent from the first absorption unit, to obtain a lean absorbent and a hydrogen sulfide rich gas stream; (d) providing the hydrogen sulfide rich gas to a Claus unit comprising a Claus furnace and a Claus catalytic stage to convert the hydrogen sulfide to obtain sulfur and a Claus tail gas; (e) providing a second regenerator with the absorbent rich in organic sulfur compounds and in carbon dioxide to obtain ...

PROCESS FOR THE TREATMENT OF LIQUEFIED HYDROCARBON GAS USING 2 -AMINO -2 (HYDROXYMETHYL) PROPANE - 1 , 3 - DIOL COMPOUNDS

A method for treating liquefied hydrocarbons comprising acid gases to remove said the 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 (1) wherein R1 and R2 may each individually be hydrogen, methyl, ethyl, n-propyl, i-propyl, n-butyl, s-butyl, 2-hydroxyethyl or propane-2,3-diol.

COMPOSITES FOR CARBON DIOXIDE CAPTURE

Composite materials and methods of preparing C02 capture include: (1) a porous solid support comprising a plurality of porous channels; and (2) a nucleophilic source associated with the porous channels of the porous solid support. The nucleophilic source is capable of converting the captured C02 to poly(C02). Methods of capturing C02 from an environment include associating the environment with the aforementioned composite materials to lead to the capture of C02 from the environment. Such methods may also include a step of releasing the captured C02 from the composite material. The associating step comprises a conversion of the captured C02 to poly(C02) in the composite material. A releasing step may also include a depolymerization of the formed poly(C02).

PROCESS WITH CONTINUOUSLY STIRRED TANK REACTOR ABSORBER AND FLASH TANK STRIPPER

The invention relates to a process for separation or purification of gaseous streams by removal of acid gases using a liquid amine solution. The process involves the steps of - contacting the gaseous stream with liquid lean amine solution in at least one continuous flow stirred-tank reactor (10; 10a, 10b; 10c); - removing a sweetened gaseous flow from said continuous flow stirred-tank reactor (10); - removing rich amine from said continuous flow stirred-tank reactor (10; 10a, 10b; 10c) for regeneration; - passing rich amine solution through at least one flash tank stripper 20; 20a, 20b; 20c; - removing acid gases and vapour from said flash tank stripper 20; 20a, 20b; 20c; - removing lean amine from said flash tank stripper for recirculation to said continuous flow stirred-tank reactor (10; 10a, 10b; 10c).

INTEGRATED PROCESS TO RECOVER HIGH QUALITY NATIVE CO2 FROM A SOUR GAS COMPRISING H2S AND CO2

The invention concerns a method for treating a hydrocarbon feed gas stream containing at least CO2 and H2S to recover a high quality purified CO2 gas stream, comprising the following steps: a. Separating said hydrocarbon feed gas stream into (i) a sweetened hydrocarbon gas stream, and (ii) an acid gas stream comprising at least CO2 and H2S; b. Introducing said gas stream (ii) into a Claus unit, thereby recovering (iii) a liquid stream of elemental sulfur and (iv) a tail gas mainly comprising N2, CO2, SO2 and H2S; c. Introducing the tail gas (iv) into a hydrogenation reactor and then into a quench contactor of the Tail Gas Treatment Unit (TGTU) thereby recovering (v) a hydrogenated tail gas stream mainly comprising N2, H2, CO, CO2 and H2S; d. Contacting said tail gas stream (v) with a non-selective amine-based solvent into a non-selective acid gas absorption unit of the TGTU thereby recovering (vi) an off gas mainly comprising N2, H2 and CO and (vii) a gas stream enriched in CO2 and H2S; ...

AQUEOUS ALKANOLAMINE ABSORBENT COMPOSITION COMPRISING PIPERAZINE FOR ENHANCED REMOVAL OF HYDROGEN SULFIDE FROM GASEOUS MIXTURES AND METHOD FOR USING THE SAME

The present invention relates to an aqueous alkanolamine solution for the removal of hydrogen sulfide from gaseous mixtures containing hydrogen sulfide. The aqueous alkanolamine solution comprises (i) an amino compound with the formula: R1R2NCH2CH(OH)CH2OH wherein R1and R2 independently represent lower alkyl groups of 1 to 3 carbon atoms, (ii) piperazine, and (iii) optionally a physical solvent, wherein said solution does not contain a strong acid. Further, the present invention relates to a process for removing hydrogen sulfide from a gaseous mixture containing hydrogen sulfide, and additionally other acid gases, if present, for example carbon dioxide, comprising the step of contacting the gaseous mixture contain hydrogen sulfide with the aqueous alkanolamine solution, preferably wherein the temperature of the aqueous alkanolamine solution is equal to or greater than 140°F. Examples of the gaseous mixtures include natural gas, synthesis gas, tail gas, and refinery gas.

CONTACTING A GAS STREAM WITH A LIQUID STREAM

A co-current contacting system is described herein. The co-current contacting system includes a co-current contactor located in-line within a pipe. The co-current contactor includes an annular support ring configured to maintain the co-current contactor within the pipe and a number of radial blades configured to allow a liquid stream to flow into the co-current contactor. The co-current contacts also includes a central gas entry cone configured to allow a gas stream to flow through a hollow section within the co-current contactor, wherein the co-current contactor provides for efficient incorporation of liquid droplets formed from the liquid stream into the gas stream. The co-current contacting system also includes a separation system configured to remove the liquid droplets from the gas stream.

CONTACTING A GAS STREAM WITH A LIQUID STREAM

A co-current contacting system is described herein. The co-current contacting system includes a co-current contactor located in-line within a pipe. The co-current contactor includes an annular support ring configured to maintain the co-current contactor within the pipe and a number of radial blades configured to allow a liquid stream to flow into the co-current contactor. The co-current contacts also includes a central gas entry cone configured to allow a gas stream to flow through a hollow section within the co-current contactor, wherein the co-current contactor provides for efficient incorporation of liquid droplets formed from the liquid stream into the gas stream. The co-current contacting system also includes a separation system configured to remove the liquid droplets from the gas stream.

METHOD OF PURIFICATION OF GAS MIXTURES, CONTAINING ACID GASES

METHOD OF REMOVING COIZ ACID GAS

DEVICE AND SYSTEM FOR REALIZATION OF METHODS HEATING-ADSORPTION

CIRCUIT AND METHODS FOR GAS CONDENSATE SEPARATION FROM HIGH-PRESSURE HYDROCARBON MIXTURES

COMPLEX METHOD OF EXTRACTION OF NATURAL COVYSOKOGO QUALITY FROM ACID GAS, INCLUDING HS AND CO

TREATMENT OF WASTE WATER TO THE LEVEL OF, SUITABLE FOR REUSE IN THE METHOD OF RECOVERY CO, AND SYSTEM

DEVICE AND SYSTEM FOR REALIZATION OF METHODS HEATING-ADSORPTION

METHOD OF REMOVING MERCAPTANS FROM GAS FLOW

USE OF GAS SEPARATING MEMBRANES FOR INCREASE CONDENSATE PRODUCTION AREAS, CONTAINING HIGH CONCENTRATION OF HYDROGEN SULFIDE

DIAMINE WITH TERT - ALKILAMINOGRUPPOI AND PRIMARY AMINO GROUP FOR USE IN ABSORPTION GAS CLEANING

METHODS OF REMOVING POLLUTING IMPURITIES FROM FLOW OF HYDROCARBONS IN CYCLIC ADSORBED PROCESS AND CONNECTED WITH THIS DEVICE AND SYSTEM

CIRCUIT PROCESSES AND METHODS OF PURIFICATION OF GAS

СПОСОБ ОБРАБОТКИ ПОТОКА ДИАМИНОВОГО АДСОРБЕНТА

Диаминовый адсорбент, который содержит термостойкие соли, регенерируют с использованием ионообменного способа, в котором ограничена концентрация термостойких солей в подаваемом потоке в катионообменную установку.

METHOD FOR PRODUCING METHANE FROM BIOMASS

ABSORBENT AND METHOD FOR SELECTIVE REMOVAL OF HYDROGEN SULFIDE

METHOD OF SEPARATION OF GASES

METHOD AND DEVICE FOR SEPARATION OF HYDROCARBONS AND POLLUTING IMPURITIES WITH THE HELP OF HEATING DEVICE FOR DESTABILIZATION AND/OR PREVENTION OF ADHESION OF SOLID SUBSTANCES

METHODS OF REMOVING POLLUTING IMPURITIES FROM FLOW OF HYDROCARBONS IN CYCLIC ADSORBED PROCESS AND CONNECTED WITH THIS DEVICE AND SYSTEM

METHOD BY HEATING ADSORPTION WITH THE USE OF ADJUSTABLE ADSORPTION FRONTS

CONTACTORS BY HEATING ADSORPTION AT VARIABLE TEMPERATURE FOR SEPARATION OF GASES

METHOD AND DEVICE FOR SEPARATION OF HYDROCARBONS AND OF POLLUTING SUBSTANCES BY MEANS OF A SPRAY GUN UNIT

METHOD OF SELECTIVE REMOVING SULFUR

METHOD OF DEEP CLEANING OF GAS FLOWS FROM IMPURITIES

METHOD OF ABSORPTION COIZ GAS MIXTURE

METHOD OF CLEANING GAS WITH THE USE OF SPECIALLY DEVELOPED ADSORBENTS WITH BY SMALL PARTICLES OF

COALESCER FOR CO-CURRENT CONTACTORS

ZEOLITE ADSORBENTS HIGH OUTER SURFACE, PROCESS FOR THEIR PREPARATION AND USES THEREOF

DECARBONATION PROCESS FOR HYDROCARBON GAS

Procédé de décarbonatation par lavage avec un solvant d'un gaz hydrocarboné, par exemple un gaz naturel. On met en contact ledit gaz avec une solution absorbante de manière à obtenir un gaz appauvri en CO2 et une solution absorbante chargée en CO2. Puis, on chauffe et on détend la solution absorbante chargée en CO2 à une pression et une température déterminées de manière à libérer une fraction gazeuse comportant des hydrocarbures et à obtenir une solution absorbante appauvrie en hydrocarbures, ladite pression et ladite température étant choisies de sorte que ladite fraction gazeuse comporte au moins 50% des hydrocarbures contenu dans ladite solution absorbante chargée en CO2 et au plus 35 % de CO2 contenu dans ladite solution absorbante chargée en CO2. Enfin, on régénère thermiquement la solution absorbante appauvrie en composés hydrocarbures de manière à libérer un effluent gazeux riche en CO2 et à obtenir un solution absorbante régénérée.

DEVICE OF CARBON DIOXIDE RECOVERY STARTING FROM A BIOGAS

PROCESS FOR THE METHANATION AND METHANATION COMPRISING A STEP OF SEPARATING AND RECIRCULATING HYDROGEN AND INSTALLATION FOR IMPLEMENTING SAID METHOD PROCESS

METHOD AND INSTALLATION FOR SEPARATING LIGHT COMPONENTS AND OF HEAVIER COMPONENTS FROM NATURAL GAS

L'invention concerne un procédé de traitement d'un gaz naturel comprenant du dioxyde de carbone, du méthane et des paraffines, comprenant une étape d'extraction des paraffines du gaz naturel dans une colonne de déparaffinage et une étape de séparation du dioxyde de carbone et du méthane dans une colonne à distiller, le fonctionnement des deux colonnes étant assuré par un couplage thermique de ces deux même colonnes à l'aide d'un échangeur de chaleur.

SYSTEM FOR THE SEPARATION AND PURIFICATION OF TWO GAS CONSTITUENT OF A GAS MIXTURE

METHOD FOR PRODUCING [...] INCORPORATING THE PRODUCTION OF HEAT FOR THE [...] USING A MEMBRANE SEPARATION.

La présente invention concerne un procédé de production de biométhane apte à alimenter un réseau de gaz naturel intégrant un procédé de fourniture de chaleur pour le chauffage de l'étape de production de biogaz, le procédé comprenant au moins des étapes de production de biogaz par fermentation anaérobique de matière organique, de prétraitement et compression du biogaz ainsi que de perméation pour obtenir, après une première séparation par perméation, un flux de biométhane et un perméat gazeux à teneur en méthane réduite; le procédé fournit en outre la chaleur nécessaire à l'étape de fermentation anaérobique via une chaudière utilisant le retentat d'une seconde étape de perméation alimentée par le perméat de la première séparation.

DEVICE AND METHOD FOR PRODUCING SYNTHESIS GAS

Le dispositif (10) de production de gaz naturel de synthèse comporte : - un moyen (805, 905) de co-électrolyse à haute température d'un mélange de dioxyde de carbone et d'eau pour produire un syngas comportant du monoxyde de carbone, du dioxyde de carbone, de l'eau et du dihydrogène, - un réacteur (105, 205) de méthanation comportant : - une entrée (110, 210), pour le syngas produit par le moyen de co-électrolyse , - une entrée (110), pour du syngas produit par électrolyse, reliée à une conduite (115) d'alimentation de syngas et - une sortie (120) pour gaz naturel de synthèse, - un moyen (125) de séparation d'eau comportant : - une entrée (130) pour gaz naturel de synthèse et - une sortie (135) pour gaz naturel de synthèse déshydraté, - une dérivation (140) d'une partie du gaz naturel de synthèse déshydraté depuis la sortie du moyen de séparation d'eau vers la conduite d'alimentation de syngas pour qu'un mélange, du syngas et du gaz naturel de synthèse dérivés, soit fourni au réacteur.

Apparatus and system for associated high speed cyclic swing adsorption process

Integration of cold solvent and acidic gas removal

APPARATUS AND METHOD FOR REMOVING ACIDIC GASES FROM NATURAL GAS

The present invention relates to an apparatus and method for removing acidic gases from natural gas. According to the present invention, the apparatus comprises: a first absorption column (101) which receives natural gas to remove acidic gas from the natural gas by using a first absorbent; a second absorption column (102) which receives the natural gas treated in the first absorption column to remove residual acid gases from the natural gas by using a second absorbent; a recovery column (103) which recovers the first absorbent discharged from the first absorption column; an absorbent mixer (104) which mixes the second absorbent discharged from the second absorption column with a semi-lean absorbent released from a middle part of the recovery column; a first line (105) which connects a lower part of the first absorption column and a middle part of the recovery column to introduce the first absorbent discharged from the first absorption column into the recovery column; a second line (106) ...

산성 가스의 포집 및 방출 방법

... 일 실시예에서, 본 발명은 조성물 내로 적어도 하나의 산성가스 포집, 그 가스를 상기 조성물로부터 방출, 및 이어서 재사용을 위한 상기 조성물의 재생 방법을 제공한다. 상기 방법은: (a) 적어도 하나의 카르복실산 염과, 적어도 하나의 물과 혼합되는 비-수계 용매를 포함하는 포집용 조성물과 접촉시킴으로써, 적어도 하나의 산성가스를 포집하는 단계; (b) 적어도 하나의 양성자성 용매 또는 제제를 상기 조성물에 첨가함으로써 상기 적어도 하나의 산성가스를 방출시키는 단계; 및 (c) 상기 조성물로부터 상기 첨가된 양성자성 용매 또는 제제를 일부 또는 완전히 제거함으로써 포집용 조성물을 재생하는 단계 를 차례로 행하는 것을 포함한다. 선택적으로는, 상기 포집용 조성물은 적어도 하나의 카르복실산 염, 및 적어도 하나의 물과 혼합되는 비수성 용매를 포함하며, 추가로 물 또는 다른 양성자성 용매를 포함한다. 또 다른 태양에서는, 본 발명의 조성물은 적어도 하나의 양성자성 용매 또는 제제를 포함하고, 상기 적어도 하나의 산성가스의 방출은 공기 흐름으로써 상기 조성물에 가열이나 탈거를 행하여 이루어진다. 본 방법은 전형적으로 이산화탄소의 포집 및 뒤이은 방출에 적용되며, 저렴한 소비재를 사용하는 편리하고 간단한 방법과, 종래 기술에 비해 현저한 이익을 제공한다.

solução aquosa de alcanolamina e processo para remover gases ácidos de uma mistura gasosa

Process

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 puritied 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 T1 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 ...

INTEGRATION OF COLD SOLVENT AND ACID GAS REMOVAL

SYSTEMS AND METHODS FOR REMOVING HEAVY HYDROCARBONS AND ACID GASES FROM A HYDROCARBON GAS STREAM

A system for removing acid gases from a sour gas stream is provided. The system includes an acid gas removal system and a heavy hydrocarbon removal system. The acid gas removal system receives the sour gas stream and separates the sour gas stream into an overhead gas stream comprised primarily of methane, and a bottom acid gas stream comprised primarily of acid gases such as carbon dioxide. The heavy hydrocarbon removal system may be placed upstream or downstream of the acid gas removal system or both. The heavy hydrocarbon removal system receives a gas stream and separates the gas stream into a first fluid stream comprising heavy hydrocarbons and a second fluid stream comprising other components. The components of the second fluid stream will depend on the composition of the gas stream. Various types of heavy hydrocarbon removal systems may be utilized.

Separating carbon dioxide and hydrogen sulfide from a natural gas stream using co-current contacting systems

Systems and methods for separating CO2 and H2S from a natural gas stream are provided herein. The system includes a first loop of co-current contacting systems configured to remove H2S and CO2 from a natural gas stream and a second loop of co-current contacting systems configured to remove the H2S from the CO2.

Process for purifying natural gas and regenerating one or more adsorbers

One exemplary embodiment can be a process for purifying a natural gas by using first and second adsorbers. The process may include passing a feed including the natural gas through the first adsorber to obtain a purified natural gas product, regenerating the second adsorber in a heating stage, and regenerating the second adsorber in a cooling stage. The heating stage may include separating a portion of the feed comprised in a regeneration gas, passing the regeneration gas to a dryer for removing water, heating the regeneration gas with a heater after exiting the dryer, and passing the regeneration gas to the second adsorber to regenerate the second adsorber. The cooling stage may include expelling at initiation of cooling at least a part of a fluid present in the second adsorber to the dryer to desorb water from a molecular sieve in the dryer, and cooling the second adsorber by circulating the regeneration gas bypassing the heater.

Swing Adsorption Processes Utilizing Controlled Adsorption Fronts

A process for reducing the loss of valuable products by improving the overall recovery of a contaminant gas component in swing adsorption processes. The present invention utilizes at least two adsorption beds, in series, with separately controlled cycles to control the adsorption front and optionally to maximize the overall capacity of a swing adsorption process and to improve overall recovery a contaminant gas component from a feed gas mixture.

Pressure-Temperature Swing Adsorption Process for the Separation of Heavy Hydrocarbons from Natural Gas Streams

The present invention relates to a pressure-temperature swing adsorption process wherein gaseous components that have been adsorbed can be recovered from the adsorbent bed at elevated pressures. In particular, the present invention relates to a pressure-temperature swing adsorption process for the separation of C 2+ hydrocarbons (hydrocarbons with at least 2 carbon atoms) from natural gas streams to obtain a high purity methane product stream. In more preferred embodiments of the present processes, the processes may be used to obtain multiple, high purity hydrocarbon product streams from natural gas stream feeds resulting in a chromatographic-like fractionation with recovery of high purity individual gaseous component streams.

Gas Purification Process Utilizing Engineered Small Particle Adsorbents

A gas separation process uses a structured particulate bed of adsorbent coated shapes/particles laid down in the bed in an ordered manner to simulate a monolith by providing longitudinally extensive gas passages by which the gas mixture to be separated can access the adsorbent material along the length of the particles. The particles can be laid down either directly in the bed or in locally structured packages/bundles which themselves are similarly oriented such that the bed particles behave similarly to a monolith but without at least some disadvantages. The adsorbent particles can be formed with a solid, non-porous core with the adsorbent formed as a thin, adherent coating on the exposed exterior surface. Particles may be formed as cylinders/hollow shapes to provide ready access to the adsorbent. The separation may be operated as a kinetic or equilibrium controlled process.

Method of producing sulfur dioxide

A method of producing sulfur dioxide is provided. A feed gas stream comprising at least 5% by volume hydrogen sulfide is provided. The feed gas stream is separated into a hydrogen sulfide stream and a hydrocarbon gas stream. An oxidant stream is provided and is combusted with the hydrogen sulfide stream to produce thermal power and a combustion stream containing sulfur dioxide and steam. Sulfur dioxide is separated from the combustion stream.

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

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.

Methods and apparatuses for processing natural gas

Methods and apparatuses for processing natural gas are provided. In a method for processing a natural gas stream, the natural gas stream is fractionated to form an overhead stream and a bottoms stream. The overhead stream is separated with a membrane to form a methane rich residual stream and a permeate stream.

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.

SYSTEMS AND METHODS FOR CARBON DIOXIDE ABSORPTION

The disclosure pertains to removal of carbon dioxide from industrial gas streams. Processes and systems are disclosed for capturing carbon dioxide from a combustion flue gas or from uncombusted natural gas by contacting with an amine blend in a first step, and an advanced solvent in a second step. The processes and systems disclosed herein increase the efficiency of carbon dioxide removal while extending the lifespan of the solvents utilized 1. A process for the removal of carbon dioxide from a gas , comprising:a) passing a first gas comprising carbon-dioxide into a first absorption zone;b) contacting the first gas with a liquid amine solvent in the first absorption zone and transferring a portion of the carbon dioxide in the first gas to the liquid amine solvent to produce a second gas comprising a reduced quantity of carbon dioxide relative to the first gas and a carbon dioxide-laden liquid amine solvent;c) passing the second gas to a second absorption zone, and contacting therein with an advanced solvent comprising an ionic liquid, a naturally-occurring enzyme, a genetically-modified enzyme, a synthetic analogue of an enzyme, or mixtures thereof;d) transferring at least a portion of the carbon dioxide in the second gas to the advanced solvent to produce a third gas comprising a reduced quantity of carbon dioxide relative to the second gas and a spent advanced solvent;e) conveying the carbon dioxide-laden liquid amine solvent of step (b) to a first regeneration zone, wherein the first regeneration zone is maintained at a temperature and pressure sufficient to liberate carbon dioxide from the carbon dioxide-laden liquid amine solvent, thereby producing a regenerated liquid amine solvent that is at least partly recycled to the first absorption zone;f) conveying the spent advanced solvent of step (d) to a second regeneration zone that is maintained at a temperature and pressure sufficient to liberate carbon dioxide from the spent advanced solvent, thereby producing a ...

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.

Methods of Removing Contaminants from Hydrocarbon Stream by Swing Adsorption and Related Apparatus and Systems

A pressure swing adsorption process for removal of C02 from natural gas streams through a combination of a selective adsorbent material containing an effective amount of a non-adsorbent filler, adsorbent contactor design, and adsorption cycle design. The removal of contaminants from gas streams, preferably natural gas streams, using rapid-cycle swing adsorption processes, such as rapid-cycle pressure swing adsorption (RC-PSA). Separations at high pressure with high product recovery and/or high product purity are provided through a combination of judicious choices of adsorbent material, gas-solid contactor, system configuration, and cycle designs. For example, cycle designs that include steps of purge and staged blow-down as well as the inclusion of a mesopore filler in the adsorbent material significantly improves product (e.g., methane) recovery. An RC-PSA product with less than 10 ppm H2S can be produced from a natural gas feed stream that contains less than 1 mole percent H2S.

SEPARATION PROCESS OF GASEOUS COMPOUNDS FROM NATURAL GAS WITH LOW EXERGY LOSSES

The present invention relates to a separation process of natural gas from gaseous compounds present at the wellhead by means of at least two adsorption columns, each containing an adsorbing solid and one operating at a higher pressure than the other, said process being characterized in that: —the compression ratio is within the range of 1.1 to 10; —the ratio between the characteristic convective time through the column and the characteristic diffusive time in the adsorbing solid is higher than 1. 1. A process for separating natural gas from gaseous compounds present at the wellhead , said gaseous compounds being selected from the group consisting of helium , nitrogen , carbon dioxide , hydrogen sulphide and combinations thereof , by means of at least two adsorption columns , each containing an adsorbing solid and one operating at a higher pressure than the other , wherein the column operating at higher pressure has an operating pressure close to that of the wellhead , said process being characterized in that:a. a compression ratio is within the range of 1.3 to 3, the compression ratio being defined as the ratio between the maximum and minimum pressure value at which the process operates;b. the ratio between a characteristic convective time through the column and a characteristic diffusive time in the adsorbing solid is higher than 1, the characteristic convective time through a column being defined as the ratio between the empty volume of the column and the volumetric flow-rate, the characteristic diffusive time in the adsorbing solid being defined as the ratio between the square of the equivalent radius of the particles of the adsorbing solid and the effective diffusivity of the gas.2. (canceled)3. The process according to claim 1 , wherein the ratio between the characteristic convective time through the column and the characteristic diffusive time in the adsorbing solid ranges from 10to 10.4. The process according to claim 1 , wherein the gaseous compounds are ...

Method for Producing Silicoaluminophosphate Sorbent

The invention relates to a method for synthesizing silicoaluminophosphate sorbents such as SAPO-56 and SAPO-47 comprising the use of a specific structure directing agent (SDA) comprising a mixture of different types of amines The structure providing agent (SDA) comprises N,N,N′,N′-tetramethyl-1,6-hexanediamine (TMHD) and a co-structure providing agent (co-SDA) selected among primary, secondary and tertiary amines comprising up to 15 carbon atoms and mixtures thereof. A preferred SDA comprises isopropylamine, dibutylamine and tripropylamine The sorbents are particularly suitable for up-grading biogas such as separating carbon dioxide from methane. 1. A method for preparing a silicoaluminophosphate sorbent comprising:providing a reaction mixture, said mixture comprising: a silicon-containing composition, an aluminum-containing composition, a phosphorous-containing composition, and a structure directing agent (SDA);crystallization of the reaction mixture thereby providing crystallized silicoalum inophosphate;recovering crystalline silicoaluminophosphate from the mixture;wherein the structure providing agent (SDA) comprises N,N,N′,N′-tetramethyl-1,6-hexanediamine (TMHD) and a co-structure providing agent (co-SDA) selected among primary, secondary and tertiary amines comprising up to 15 carbon atoms and mixtures thereof.2. The method according to claim 1 , wherein the co-SDA is selected among primary amines comprising a saturated hydrocarbon comprising up to 6 carbon atoms.3. The method according to claim 1 , wherein the silicoaluminophosphate sorbent is selected among SAPO-47 and SAPO-56.4. The method according to claim 1 , wherein the silicoaluminophosphate sorbent is SAPO-56.5. The method according to claim 1 , wherein the SDA comprises up to about 75% wt of the co-SDA.6. The method according to claim 1 , wherein the primary claim 1 , secondary and tertiary amines comprise saturated hydrocarbons.7. The method according to claim 6 , wherein the saturated hydrocarbons ...

System for the Capture and Release of Acid Gases

In one aspect, the invention provides a method for the capture of at least one acid gas in a composition, the release of said gas from said composition, and the subsequent regeneration of said composition for re-use, said method comprising performing, in order, the steps of: (a) capturing the at least one acid gas by contacting said at least one gas with a capture composition comprising at least one salt of a carboxylic acid and at least one water-miscible non-aqueous solvent; (b) releasing said at least one acid gas by adding at least one protic solvent or agent to said composition; and (c) regenerating the capture composition by partial or complete removal of said added protic solvent or agent from said composition. Optionally, said capture composition comprising at least one salt of a carboxylic acid and at least one water-miscible non-aqueous solvent additionally comprises water or another protic solvent. In another aspect, the invention envisages a composition which additionally comprises at least one protic solvent or agent and release of the at least one acid gas is achieved solely by subjecting the composition to the application of heat or stripping with a stream of air. The method is typically applied to the capture and subsequent release of carbon dioxide, and offers a convenient and simple process which uses inexpensive consumables and offers significant advantages over the methods of the prior art. 147-. (canceled)48. A method for the capture of at least one acid gas in a composition , the release of said gas from said composition , and the subsequent regeneration of said composition for re-use , said method comprising performing , in order , the steps of:(a) capturing the at least one acid gas by contacting said at least one gas with a capture composition comprising at least one salt of a carboxylic acid, at least one non-aqueous solvent and optionally at least one protic solvent or agent;(b) releasing said at least one acid gas by subjecting said ...

METHOD, SYNTHESIS, ACTIVATION PROCEDURE AND CHARACTERIZATION OF AN OXYGEN RICH ACTIVATED POROUS CARBON SORBENT FOR SELECTIVE REMOVAL OF CARBON DIOXIDE WITH ULTRA HIGH CAPACITY

The present disclosure pertains to materials for COadsorption at pressures above 1 bar, where the materials include a porous carbon material with a surface area of at least 2800 m/g, a total pore volume of at least 1.35 cm/g, and a carbon content of 80%-95%. The porous carbon material is prepared by heating organic polymer precursors or biological materials in the presence of KOH at 700° C.-800° C. The present disclosure also pertains to materials for the separation of COfrom natural gas at partial pressures above 1 bar, where the material includes a porous carbon material with a surface area of at least 2000 m/g, a total pore volume of at least 1.00 cm/g, and a carbon content of greater than 90%. The porous carbon materials can be prepared by heating organic polymer precursors or biological materials in the presence of KOH at 600° C.-700° C. 1. A material for COadsorption at pressures above 1 bar , said material comprising:{'sup': 2', '3, 'claim-text': 'wherein the temperature of activation is between 700° C. and 800° C.', 'wherein the porous carbon material is prepared by heating an organic polymer precursor or biological material in the presence of KOH, and'}, 'a porous carbon material with a surface area of at least 2800 m/g, a total pore volume of at least 1.35 cm/g, and a carbon content of between 80% and 95% as measured by X-ray photoelectron spectroscopy,'}2. The material of claim 1 , wherein the porous carbon material is prepared by heating an organic polymer precursor.3. The material of claim 2 , wherein the organic polymer precursor comprises oxygen in a functional group.4. The material of claim 3 , wherein the functional group is a furyl.5. The material of claim 4 , wherein the organic polymer precursor polymerizes to form polyfurfuryl alcohol.6. The material of claim 5 , wherein the polyfurfuryl alcohol is prepared by the polymerization of furfuryl alcohol with a catalyst.7. The material of claim 6 , where the catalyst is iron(III) chloride.8. The ...

SUBSEA FLUID PROCESSING SYSTEM

A subsea fluid processing system which receives a wellstream flow. The subsea fluid processing system includes a pressure control device which regulates a pressure of the wellstream flow, a gas-liquid separator unit which receives the wellstream flow downstream of the pressure control device and which provides a liquid stream and a gas stream, a first membrane separator which receives the gas stream and which provides a retentate stream and a permeate stream, a compressor which receives the permeate stream and which provides a compressed permeate stream, and a discharge cooler which receives the compressed permeate stream and which provides a cooled compressed permeate stream for injection into a subsurface reservoir. A density of the cooled compressed permeate stream is higher than a density of the compressed permeate stream. 17-. (canceled)8: A subsea fluid processing system configured to receive a wellstream flow , the subsea fluid processing system comprising:a pressure control device configured to regulate a pressure of the wellstream flow;a gas-liquid separator unit configured to receive the wellstream flow downstream of the pressure control device and to provide a liquid stream and a gas stream;a first membrane separator configured to receive the gas stream and to provide a retentate stream and a permeate stream;a compressor configured to receive the permeate stream and to provide a compressed permeate stream; anda discharge cooler configured to receive the compressed permeate stream and to provide a cooled compressed permeate stream for injection into a subsurface reservoir,wherein, a density of the cooled compressed permeate stream is higher than a density of the compressed permeate stream.9: The subsea fluid processing system as recited in claim 8 , further comprising:a membrane unit; anda demister,wherein,the membrane unit comprises the first membrane separator and a second membrane separator which is arranged in series with the first membrane separator, ...

ADSORPTION PROCESS FOR TREATING NATURAL GAS

A process of treating a natural gas stream is provided comprising sending natural gas stream through a first adsorbent bed to remove water and heavy hydrocarbons (C8+) to produce a partially treated gas stream in which the first adsorbent bed is regenerated by a temperature swing adsorption process and then sending the partially treated gas stream through a second adsorption bed to remove carbon dioxide and lighter hydrocarbons (C7−) to produce a purified natural gas stream wherein said second adsorption bed is regenerated by a temperature pressure swing adsorption process. 1. A process of treating a natural gas stream comprisingsending said natural gas stream through a first adsorbent bed to remove water and heavy hydrocarbons (C8+) to produce a partially treated gas stream wherein said first adsorbent bed is regenerated by a temperature swing adsorption process; andsending said partially treated gas stream through a second adsorption bed to remove carbon dioxide and lighter hydrocarbons (C7−) to produce a purified natural gas stream wherein said second adsorption bed is regenerated by a temperature pressure swing adsorption process.2. The process of wherein said natural gas stream comprises less than about 3 vol % carbon dioxide.3. The process of wherein a closed loop or semi-closed loop regeneration gas stream is used to regenerate said second adsorbent bed.4. The process of wherein a semi-closed loop regeneration gas stream is used to regenerate said second adsorbent bed.5. The process of wherein said temperature pressure swing adsorption process comprises a series of steps in order comprising adsorption claim 1 , co-current depressurization claim 1 , closed-loop heating claim 1 , a purge with heating claim 1 , a purge without heating claim 1 , repressurization of the adsorbent bed and cooling with feed and then withdrawal of product.6. The process of wherein said temperature pressure swing adsorption process comprises a series of steps in order comprising ...

Mixing and Heat Integration of Melt Tray Liquids in a Cryogenic Distillation Tower

A cryogenic distillation tower for separating a feed stream. The tower includes a distillation section. A controlled freeze zone section is situated above the distillation section and forms a solid from the feed stream. The controlled freeze zone section includes a spray assembly in an upper section and a melt tray assembly in a lower section. The melt tray assembly includes at least one vapor stream riser that directs the vapor from the distillation section into liquid retained by the melt tray assembly, and one or more draw-off openings positioned to permit a portion of the liquid to exit the controlled freeze zone section. The portion of the liquid indirectly exchanges heat with a heating fluid. One or more return inlets return the portion of the liquid to the melt tray assembly after it has been heated in the heat exchanger. 1. A cryogenic distillation tower for separating a feed stream , the distillation tower comprising:a distillation section permitting vapor to rise upwardly therefrom;one or more lines for directing the feed stream into the distillation tower; a spray assembly in an upper section of the controlled freeze zone, and', at least one vapor stream riser that directs the vapor from the distillation section into liquid retained by the melt tray assembly, and', 'one or more draw-off openings positioned to permit a portion of the liquid retained by the melt tray assembly to exit the controlled freeze zone section;, 'a melt tray assembly in a lower section of the controlled freeze zone, wherein the melt tray assembly includes'}], 'a controlled freeze zone section situated above the distillation section, the controlled freeze zone constructed and arranged to form a solid from the feed stream, the controlled freeze zone section including'}a heat exchanger arranged to heat the portion of the liquid through indirect heat exchange with a heating fluid; andone or more return inlets that return the portion of the liquid to the melt tray assembly after the ...

ZEOLITE ADSORBENTS HAVING A HIGH EXTERNAL SURFACE AREA AND USES THEREOF

The present invention concerns the use, for gas separation, of at least one zeolite adsorbent material comprising at least one FAU zeolite, said adsorbent having an external surface area greater than 20 m·g, a non-zeolite phase (PNZ) content such that 0 Подробнее

Hydrated porous materials for selective co2 capture

In some embodiments, the present disclosure pertains to methods of capturing CO 2 from an environment by hydrating a porous material with water molecules to the extent thereby to define a preselected region of a plurality of hydrated pores and yet to the extent to allow the preselected region of a plurality of pores of the porous material to uptake gas molecules; positioning the porous material within a CO 2 associated environment; and capturing CO 2 by the hydrated porous material. In some embodiments, the pore volume of the hydrated porous material includes between 90% and 20% of the pre-hydrated pore volume to provide unhydrated pore volume within the porous material for enhanced selective uptake of CO 2 in the CO 2 associated environment. In some embodiments, the step of capturing includes forming CO 2 -hydrates within the pores of the porous material, where the CO 2 ·n/H 2 O ratio is n<4.

System for flare gas recovery using gas sweetening process

The present disclosure includes systems and methods that integrate a flare gas recovery process with a gas sweetening process used in oil and gas refining. A flare gas recovery system includes a primary gas sweetening unit and a liquid-driven ejector in continuous fluid communication with the primary gas sweetening unit. The ejector includes an inlet configured to receive a motive fluid including a regenerable amine solvent in a lean state from the primary gas sweetening unit, a gas inlet configured to receive a suction fluid including a gas, and a fluid outlet configured to either directly or indirectly discharge to the primary gas sweetening unit a two-phase fluid including a mixture of the suction fluid and the amine solvent in a rich state.

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.

PROCESS FOR SEPARATING HYDROGEN SULFIDE FROM GASEOUS MIXTURES USING A HYBRID SOLVENT MIXTURE

Disclosed is a process for regenerating a hybrid solvent used to remove contaminants from a fluid stream and to provide an improved yield of purified fluid. Said process comprises at least one purification unit () and at least one regeneration unit () wherein condensed water () from the regeneration unit is combined with the regenerated lean hybrid solvent () prior to reuse in the purification unit and none of the condensed water is recycled into the regeneration unit. 1. A process for treating a hydrocarbon fluid stream containing one or more acid gas comprising the steps of:i) absorbing one or more acid gas from the hydrocarbon fluid stream in a purification unit by counter currently contacting the fluid stream with a lean hybrid solvent comprising a chemical solvent, a physical solvent, and water to produce a purified hydrocarbon fluid stream and a rich hybrid solvent comprising hybrid solvent, hydrocarbons, and acid gas(es);ii) passing the rich hybrid solvent to a separation unit to separate hydrocarbons from the rich hybrid solvent providing a hydrocarbon stream and a rich hybrid solvent stream containing acid gas(es) having a low hydrocarbon content;iii) passing the rich hybrid solvent stream containing acid gas(es) with low hydrocarbon content to a regenerating unit to produce a gas stream comprising acid gas(es), water vapor, and residual hybrid solvent and a regenerated lean hybrid solvent stream;iv) condensing the gas stream to provide an acid gas stream and a water stream comprising residual acid gases and/or hybrid solvent;v) passing all or a portion of the water stream to a separator to separate residual acid gas(es) providing a water with residual hybrid solvent stream;vi) combining the water with residual hybrid solvent stream and the regenerated lean hybrid solvent stream;andvii) introducing the combined water with residual hybrid solvent stream and regenerated lean hybrid solvent stream into the purification unit,wherein no portion of said water ...

METHOD AND SYSTEM FOR UPGRADING BIOGAS

A method for providing renewable natural gas (RNG) includes removing hydrogen sulfide and/or carbon dioxide from biogas to provide partially purified biogas, which may be stored in a mobile storage tank. The partially purified biogas is transported to a biogas upgrading facility, at least partially by truck, rail, or ship. At the biogas upgrading facility, the partially purified biogas is further purified to provide the RNG, which can be injected into a distribution system (e.g., natural gas grid) and/or provided for use in transportation. 145-. (canceled)46. A method for upgrading biogas comprising:(a) obtaining biogas from a plurality of biogas sources, including a first biogas from a first biogas source and a second other biogas from a second other biogas source;(b) removing one or more components from the first biogas to produce a first partially purified biogas having a non-methane content of at least 10%, said one or more components comprising hydrogen sulfide, carbon dioxide, or a combination thereof, said one or more components removed using at least one stationary purification system;(c) transporting a first vessel containing the first partially purified biogas to a biogas upgrading facility;(d) removing one or more components from the second biogas to produce a second partially purified biogas, said one or more components comprising hydrogen sulfide, carbon dioxide, or a combination thereof, said one or more components removed using at least one stationary purification system;(e) optionally, transporting a second vessel containing the second partially purified biogas to the biogas upgrading facility;(f) at the biogas upgrading facility, removing at least one component from a gas stream comprising the first partially purified biogas, the second partially purified biogas, or a combination thereof, to produce renewable natural gas having a heating value that is greater than a heating value of any one of the first and second partially purified biogases;(g) ...

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.

AQUEOUS ABSORBENT COMPOSITION FOR ENHANCED REMOVAL OF HYDROGEN SULFIDE FROM GASEOUS MIXTURES AND METHOD FOR USING THE SAME

The present invention relates to an aqueous alkanolamine solution for the removal of hydrogen sulfide from gaseous mixtures containing hydrogen sulfide. The aqueous alkanolamine solution comprises (i) an amino compound with the formula: 18-. (canceled)9. A process for removing hydrogen sulfide from a gaseous mixture comprising hydrogen sulfide comprising the step of: (i) 3-(dimethylamino)-1,2-propanediol,', '(ii) piperazine,', 'and', '(iii) optionally a physical solvent', 'wherein said aqueous alkanolamine solution does not contain an acid having a pKa of 8 or less or an acid-forming material capable of forming in aqueous medium an acid having a pKa of 8 or less., 'A) contacting the gaseous mixture with an aqueous alkanolamine solution wherein the aqueous alkanolamine solution consists of101. The process of claim wherein(i) the 3-(dimethylamino)-1,2-propanediol is present in an amount from 0.1 to 75 weight percent,and(ii) the piperazine is present in an amount from 0.1 to 15 weight percent,wherein weight percent is based on the total weight of the aqueous alkanolamine solution.111. The process of claim wherein the physical solvent is present in an amount from 1 to 75 weight percent based on the total weight of the aqueous alkanolamine solution.123. The process of claim wherein the physical solvent (iii) is selected from cyclotetramethylenesulfone , dimethyl ethers of polyethylene glycol , 1 ,3-dimethyl-3 ,4 ,5 ,6-tetrahydro-2(1H)-pyrimidinone , N-formylmorpholine , N-acetylmorpholine , triethylene glycol monomethyl ether , or mixtures thereof.131. The process of claim further comprising the step ofB) steam stripping the aqueous alkanolamine solution such that an acid gas-lean aqueous alkanolamine solution is formed which may be used in said contacting step.141. The process of claim wherein the temperature of the aqueous alkanolamine solution is equal to or greater than 140° F. The present invention relates to a composition comprising an aqueous solution of ...

GAS SEPARATION MEMBRANE, GAS SEPARATION MODULE, GAS SEPARATION APPARATUS, AND GAS SEPARATION METHOD

A gas separation membrane has a gas separation layer containing a poly(benzoxazole-imide) compound in which the poly(benzoxazole-imide) compound having structural units represented by General formulae (I) and (II), or structural units represented by General formulae (I), (II) and (III) satisfies a specific molar quantity condition. 8. The gas separation membrane according to claim 1 , wherein the gas separation layer further contains a polymer other than the poly(benzoxazole-imide) compound.10. The gas separation membrane according to claim 9 , wherein Ris CORor Si(R)where Rand Reach represent an alkyl group.11. The gas separation membrane according to claim 9 , wherein Ris CORwhere Rrepresents an alkyl group.12. The gas separation membrane according to claim 9 , wherein Ris COCH.13. The gas separation membrane according to claim 9 , wherein Ris Si(R)where Rrepresents an alkyl group.14. The gas separation membrane according to claim 9 , wherein a temperature of the heat-treating is 300° C. to 600° C.15. The gas separation membrane according to claim 1 , wherein the gas separation membrane is an asymmetric membrane.16. The gas separation membrane according to claim 1 , further comprising:a siloxane compound layer disposed on the gas separation layer, {'br': None, 'Si ratio=(Si−Kα X-ray intensity after immersion in chloroform)/(Si−Kα X-ray intensity before immersion in chloroform)\u2003\u2003Mathematical expression (I)'}, 'wherein a Si ratio of the siloxane compound layer after immersion in chloroform to the siloxane compound layer before immersion in chloroform, the Si ratio being calculated by Mathematical expression (I), is 0.6 to 1.0;'}17. The gas separation membrane according to claim 16 , wherein the siloxane compound layer contains an organopolysiloxane compound having a structure in which siloxane compounds are linked to each other through a linking group selected from the group consisting of *—O-M-O—* claim 16 , *—S-M-S—* claim 16 , *—NRC(═O)—* claim 16 , *— ...

GAS SEPARATION MEMBRANE, GAS SEPARATION MODULE, GAS SEPARATION APPARATUS, AND GAS SEPARATION METHOD

A gas separation membrane has a gas separation layer containing a cellulose resin, and an organopolysiloxane compound layer disposed on the gas separation layer in which Si ratio of the organopolysiloxane compound layer after immersion in chloroform to the organopolysiloxane compound layer before immersion in chloroform, the Si ratio being calculated by Mathematical expression (I), is 0.6 to 1.0. 1. A gas separation membrane comprising:a gas separation layer containing a cellulose resin; andan organopolysiloxane compound layer disposed on the gas separation layer, {'br': None, 'Si ratio=(Si—Kα X-ray intensity after immersion in chloroform)/(Si—Kα X-ray intensity before immersion in chloroform)\u2003\u2003Mathematical expression (I)'}, 'wherein a Si ratio of the organopolysiloxane compound layer after immersion in chloroform to the organopolysiloxane compound layer before immersion in chloroform, the Si ratio being calculated by Mathematical expression (I), is 0.6 to 1.0.'}2. The gas separation membrane according to claim 1 ,{'sup': a', 'b', 'b', 'c', 'c', '−', '+', 'd', '−', '+', 'e', '−', '+', 'f, 'sub': 2', '2', '2', '2', '2', '2', '2', '2', '2', '2', '2', '2', '2', '2', '2', '2', '2', '3', '3', '3', '3', '3, 'wherein the organopolysiloxane compound layer has a structure in which organopolysiloxane compounds are linked to each other through a linking group selected from *—O-M-O—*, *—S-M-S—*, *—NRC(═O)—*, *—NRC(═O)NR—*, *—O—CH—O—*, *—S—CHCH—*, *—OC(═O)O—*, *—CH(OH)CHOCO—*, *—CH(OH)CHO—*, *—CH(OH)CHS—*, *—CH(OH)CHNR—*, *—CH(CHOH)CHOCO—*, *—CH(CHOH)CHO—*, *—CH(CHOH)CHS—*, *—CH(CHOH)CHNR—*, *—CHCH—*, *—C(═O)ON(R)—*, *—SON(R)—*, and *—POHN(R)—*, and'}the organopolysiloxane compound layer contains 10 to 5,000 ppm of an organic solvent,{'sup': a', 'b', 'c', 'd', 'e', 'f, 'where M represents a divalent to tetravalent metal atom; R, R, R, R, R, and Reach independently represent a hydrogen atom or an alkyl group; and the symbol * represents a linking site.'}3. The gas ...

HIGH RECOVERY PROCESS FOR PURIFICATION OF MULTICOMPONENT GASES

The process of the present invention provides high recovery and low capital cost giving it an economic advantage over previously known purification processes. The present process has particular applicability to the purification of synthesis gases comprising at least hydrogen (H), carbon monoxide (CO), methane (CH), CO, and HO to obtain a gas stream including at least H, CO, and CH, that is substantially free of HO and CO. The process also has applicability to the purification of natural gases inclusive of at least CH, N, CO, and HO to produce a gas stream including at least CHand N, but which is substantially free of HO and CO. 1. A cyclic pressure swing adsorption (PSA) process for the substantial removal of HO and COcomprising: contacting a multicomponent feed gas at elevated pressure with an adsorbent bed to obtain a multicomponent product gas substantially free of HO and COwith high recovery of the product gas components , the process wherein a plurality of adsorbent beds in a PSA system are subjected to a series of process steps which include an adsorption step , three or more pressure equalization steps at decreasing pressure , a blowdown step , a purge step in which the purge gas comprises a portion of the product gas or a gas originating externally from the process that is substantially free of HO and COand comprises at least one of the major components of the product gas , three or more pressure equalization steps at increasing pressure , and a final repressurization step , wherein each of the adsorbent beds contains at least one adsorbent layer for the substantial removal of COcharacterized by:{'sub': 2', '2', '2, 'i. a COloading capacity of greater than or equal to 0.1 mol COper kg of adsorbent at a COpartial pressure of 1000 Pa at 300 K, and'}ii. a differential capacity of the product gas components of less than or equal to 0.1 mol per kg of adsorbent, where the differential capacity is defined as the difference between the loading capacity at partial ...

System for flare gas recovery using gas sweetening process

The present disclosure includes systems and methods that integrate a flare gas recovery process with a gas sweetening process used in oil and gas refining. A flare gas recovery system includes a primary gas sweetening unit and a liquid-driven ejector in continuous fluid communication with the primary gas sweetening unit. The ejector includes an inlet configured to receive a motive fluid including a regenerable amine solvent in a lean state from the primary gas sweetening unit, a gas inlet configured to receive a suction fluid including a gas, and a fluid outlet configured to either directly or indirectly discharge to the primary gas sweetening unit a two-phase fluid including a mixture of the suction fluid and the amine solvent in a rich state.

SYSTEM AND METHOD FOR SEPARATING CARBON DIOXIDE FROM NATURAL GAS

A system and method for separating COfrom natural gas, which ensure that no clogging or deterioration occurs in a gas separation membrane even after the gas separation membrane is used to remove carbon dioxide from the natural gas under conditions in which the natural gas is pressurized. First, an HS remover removes hydrogen sulfide from raw natural gas. Then, a compressor pressurizes the natural gas from which HS has been removed. After that, a cooler cools the pressurized natural gas so as to condense components that are a part of the natural gas. A gas/liquid separator removes the condensed components, and a COseparator, including a separation membrane for separating COremoves COfrom the natural gas from which the condensed components have been removed. An expander, which shares a drive shaft with the compressor, expands the natural gas from which COhas been removed and recovers energy therefrom. 1. A system for separating carbon dioxide from natural gas containing carbon dioxide and hydrogen sulfide , comprising:a hydrogen sulfide remover for removing hydrogen sulfide from the natural gas;a compressor for pressurizing the natural gas from which hydrogen sulfide has been removed by the hydrogen sulfide remover;a cooler for cooling the natural gas that has been pressurized by the compressor so as to condense a component that is a part of the natural gas;a gas/liquid separator for removing the condensed component from the natural gas that has been cooled by the cooler;a carbon dioxide separator including a separation membrane for separating carbon dioxide from the natural gas from which the condensed component has been removed by the gas/liquid separator; andan expander for expanding the natural gas from which carbon dioxide has been separated by the carbon dioxide separator and recovering energy from the natural gas.2. The system according to claim 1 , wherein the cooler is a heat exchanger for exchanging heat between the natural gas that has been pressurized by ...

PROCESS FOR REMOVING SULFUR COMPOUNDS FROM NATURAL GAS STREAMS

A process for the removal of sulfur compounds from a feed stream. A first separation zone removes sulfur compounds and produces a partially cleaned stream. A first adsorption zone adsorbs the remaining organic sulfur compounds on a regenerable adsorbent a produces a treated gas stream. A portion of the treated gas stream may regenerate the adsorbent in the first adsorption zone by removing organic sulfur compounds. The organic sulfur compound rich stream can be passed to a non-regenerable adsorption zone. The non-regenerable adsorption zone will separate out the organic sulfur compounds and provide a re-treated gas stream which may be recycled to a portion of the process. The non-regenerable adsorption zone may include regenerable adsorbent, but the zone is not operated to regenerate the adsorbent while it is in the non-regenerable adsorption zone. 1. A process for the treatment of a natural gas feed stream comprising:passing a natural gas feed stream to a separation zone to separate carbon dioxide and hydrogen sulfide from the natural gas feed stream to provide an at least partially cleaned stream;passing the at least partially cleaned stream to a first adsorption zone to separate organic sulfur compounds and provide a treated gas stream, wherein the first adsorption zone comprises one or more beds with a regenerable adsorbent;regenerating the regenerable adsorbent of the first adsorption zone with a portion of the treated gas stream to provide an organic sulfur rich stream; and,passing the organic sulfur rich stream to a second adsorption zone to separate organic sulfur compounds and provide a re-treated gas stream.2. The process of claim 1 , wherein the second adsorption zone comprises a non-regenerable adsorption zone.3. The process of claim 2 , wherein the non-regenerable adsorption zone comprises one or more beds with a regenerable adsorbent and the non-regenerable adsorption zone is operated in a non-regenerable manner.4. The process of further comprising: ...

PRODUCTION OF BIOMETHANE USING MULTIPLE TYPES OF MEMBRANE

The invention relates to a process for recovering methane from digester biogas or landfill gas. More specifically, the invention pertains to a method for producing biomethane that removes impurities from a compressed digester biogas with staged membrane modules of at least two different types, to produce a biomethane having at least 94% CH, below 3% of CO, and below 4 ppm of HS. 1. A method for producing biomethane , comprising:compressing a biogas feed in a compressor to produce a compressed feed stream;passing said compressed feed stream to a first separation stage comprising at least one polymeric gas separation membrane to retain a first gas mixture comprising at least 60% of methane, and to permeate a first low-quality gas mixture comprising impurities present in said biogas feed stream and less than 20% of methane;sending a stream of said first gas mixture into a second separation stage comprising at least one polymeric gas separation membrane, to retain a second gas mixture containing at least 94% of methane, and to permeate a second permeate gas mixture comprising impurities present in said biogas feed stream and less than 70% of methane;recycling a stream of said second permeate gas mixture to said compressor; andwithdrawing said second gas mixture from said second separation stage as biomethane, wherein said membrane of said first separation stage is substantially different from said membrane of said second separation stage, and said method excludes the use of regenerable adsorbent.2. The method of claim 1 , wherein said biogas feed contains 40-75% of methane (“CH”) claim 1 , and impurities of:{'sub': '2', 'up to 10% nitrogen (“N”);'}{'sub': '2', 'up to 1% oxygen (“O”);'}{'sub': '2', '20-55% of carbon dioxide (“CO”);'}{'sub': '2', 'up to 5,000 ppm of hydrogen sulfide (“HS”);'}siloxanes;up to 2,000 ppm of VOC's; andwater.3. The method of claim 1 , further comprising a step of passing said compressed feed stream to a water removal apparatus to remove water ...

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.

REMOVAL OF SULFUR COMPOUNDS IN AN ACID GAS STREAM GENERATED FROM SOLVENT-BASED GAS TREATING PROCESS

The invention involves a process for treating a natural gas stream comprising sending the natural gas stream first to an adsorbent unit for removal of mercury. Then the gas stream is sent to an absorbent unit containing a chemical solvent and a physical solvent for removal of carbon dioxide, hydrogen sulfide, carbonyl sulfide and organic sulfur compounds to produce a partially purified natural gas stream. This stream is dehydrated and becomes the product stream. The partially purified natural gas stream to a dehydration unit to remove water to produce a natural gas product stream. The impurities absorbed by the absorption unit are removed and a liquid stream is separated that contains the sulfur impurities. This liquid stream may be purified and stabilized before being shipped for further treatment. 1. A process for treating a natural gas stream comprising:a) sending said natural gas stream to an absorbent unit containing a chemical solvent and a physical solvent for removal of carbon dioxide, hydrogen sulfide, carbonyl sulfide and organic sulfur compounds to produce a partially purified natural gas stream;b) then sending said partially purified natural gas stream to a dehydration unit to remove water to produce a natural gas product stream; andc) removing said sulfur compounds from said absorbent unit to produce a liquid comprising said sulfur compounds.2. The process of further comprising sending said natural gas stream to an adsorbent unit for removal of mercury.3. The process of wherein said chemical solvent is selected from the group consisting of amines claim 1 , ammonia claim 1 , potassium carbonate and sodium carbonate.4. The process of wherein said physical solvent is selected from the group consisting of dimethyl ethers of polyethylene glycol claim 1 , propylene carbonate claim 1 , methanol claim 1 , N-methyl-2-pyrrolidone claim 1 , and sulfolane.5. The process of wherein a liquid comprising sulfur compounds and a residual gas are separated from a ...

Floating Liquefied Natural Gas Pretreatment System

A pretreatment system and method for a floating liquid natural gas (“FLNG”) facility are presented. The inlet natural gas stream flows through a membrane system to remove carbon dioxide and a heat exchanger, producing first and second cooled CO-depleted non-permeate streams. The first cooled CO-depleted non-permeate stream is routed to additional pretreatment equipment, while the second cooled CO-depleted non-permeate stream is routed directly to a LNG train. Alternatively, the inlet natural gas stream may flow through a membrane system to produce a single cooled CO-depleted non-permeate stream that is routed to the LNG train after sweetening and dehydration. Because the pretreatment system delivers the incoming gas stream to the LNG train at a lower temperature than conventional systems, less energy is needed to convert the gas stream to LNG. In addition, the pretreatment system has a smaller footprint than conventional pretreatment systems. 1. A pretreatment system for a floating liquid natural gas (“FLNG”) facility , the pretreatment system comprisinga membrane system configured to receive an inlet natural gas stream; and a first heated permeate stream,', 'a first cooled non-permeate stream, and', 'a second cooled non-permeate stream; and, 'a heat exchanger configured to receive and cross-exchange heat between a cooled permeate stream and a cooled non-permeate stream from the membrane system and a substantially water-free natural gas outlet stream to producean additional pretreatment process equipment;means to route the first cooled non-permeate stream to the additional pretreatment process equipment; andmeans to route the second cooled non-permeate to an LNG train.3. A pretreatment system according to wherein the membrane system is a COremoval membrane system.5. A pretreatment system according to wherein the mercury removal system includes a mercury/HS removal bed.6. A pretreatment system according to wherein at least one of the first and second cooled non- ...

Floating Liquefied Natural Gas Pretreatment System

A pretreatment system and method for a floating liquid natural gas (“FLNG”) facility are presented. The inlet natural gas stream flows through a membrane system to remove carbon dioxide and a heat exchanger, producing first and second cooled CO-depleted non-permeate streams. The first cooled CO-depleted non-permeate stream is routed to additional pretreatment equipment, while the second cooled CO-depleted non-permeate stream is routed directly to a LNG train. Alternatively, the inlet natural gas stream may flow through a membrane system to produce a single cooled CO-depleted non-permeate stream that is routed to the LNG train after sweetening and dehydration. Because the pretreatment system delivers the incoming gas stream to the LNG train at a lower temperature than conventional systems, less energy is needed to convert the gas stream to LNG. In addition, the pretreatment system has a smaller footprint than conventional pretreatment systems. 1. A pretreatment method for cooling and purifying a natural gas stream for processing into LNG , the method comprising:passing an inlet natural gas stream through a membrane system to produce a cooled permeate stream and a cooled non-permeate stream;routing the cooled permeate and non-permeate streams directly to a heat exchanger; a first cooled permeate stream,', 'a first cooled non-permeate stream, and', 'a second cooled non-permeate stream;, 'cross-exchanging heat in a heat exchanger between the cooled permeate and non-permeate streams and a substantially water-free natural gas outlet stream and to producerouting the first cooled non-permeate stream to additional pretreatment equipment; anddirecting the second cooled non-permeate stream directly to an LNG train.2. A pretreatment method according to further comprising:processing the inlet natural gas stream in a mercury removal system to form a substantially mercury-free natural gas stream.3. A pretreatment method according to wherein the mercury removal system is a mercury/ ...

CARBON DIOXIDE GAS SEPARATION METHOD AND CARBON DIOXIDE GAS SEPARATION APPARATUS

Carbon dioxide gas in a high-pressure gas to be treated is stably separated using a separation membrane. Upon separating carbon dioxide gas in a high-pressure gas to be treated using a separation membrane module including a separation membrane, a preliminary boosted gas is supplied to the separation membrane module before the supply of natural gas is started to boost a pressure on a primary side of the separation membrane to a preliminary pressure between a stand-by pressure and an operating pressure. Thus, when the supply of a high-pressure gas to be treated is started to increase the pressure of the separation membrane module to an operating pressure, an abrupt decrease in temperature of the gas to be treated can be suppressed. 1. A carbon dioxide gas separation method of permeating carbon dioxide gas in a gas to be treated from a primary side to a secondary side of a separation membrane provided in a separation membrane module to reduce the carbon dioxide gas in the gas to be treated , the method characterized by comprising:a step of supplying a preliminary boosted gas to the primary side of the separation membrane to boost the pressure to a preliminary pressure between a stand-by pressure and an operating pressure, before the gas to be treated is supplied at a supply pressure higher than the stand-by pressure to the separation membrane module in a state of the stand-by pressure lower than the operating pressure when the carbon dioxide gas is permeated through the separation membrane, in order to maintain a temperature of the gas to be treated in which a decrease in pressure occurs to a temperature higher than a condensation temperature of the carbon dioxide gas or a solidification temperature of the carbon dioxide gas; anda subsequent step of supplying the gas to be treated to the separation membrane module to increase the pressure of the separation membrane module to the operating pressure and to reduce the carbon dioxide gas in the gas to be treated.2. The ...

POROUS CO-POLYMERIC GEL COMPOSITIONS, POROUS CARBON COMPOSITIONS, AND METHODS FOR SYNTHESIS THEREOF

The present invention discloses novel porous polymeric compositions comprising random copolymers of amides, imides, ureas, and carbamic-anhydrides, useful for the synthesis of monolithic bimodal microporous/macroporous carbon aerogels. It also discloses methods for producing said microporous/macroporous carbon aerogels by the reaction of a polyisocyanate compound and a polycarboxylic acid compound, followed by pyrolytic carbonization, and by reactive etching with COat elevated temperatures. Also disclosed are methods for using the microporous/macroporous carbon aerogels in the selective capture and sequestration of carbon dioxide. 1. A porous co-polymeric composition comprising gels or aerogels , said composition including at least an amide linkage , an imide linkage and a urea linkage present in any random order.27-. (canceled)9. The composition of claim 8 , wherein R1 claim 8 , R2 claim 8 , R3 claim 8 , and R4 are H.10. (canceled)11. A porous co-polymeric composition comprising gels and/or aerogels:{'br': None, 'sub': 't', '-{-[G1-L5-G2]s-[G1-L6-G2]-[G1-L7-G2]u-}p-\u2003\u2003(Ib)'}wherein G1 is a moiety selected from C1-C10 straight chain alkyl or branched alkyl or cycloalkyl, alkylaryl, aryl, heteroalkyl, heterocyclylalkyl, or heteroaryl, each of which is optionally substituted;G2 is a moiety selected from alkyl, cycloalkyl, heteroalkyl, heterocylcoalkyl, alkylaryl, cycloalkylaryl, alkylheteroaryl, cycloalkylheteroaryl, an arene ring system, or a heteroarene ring system, each of which is optionally substituted;L5, L6, and L7 represent one or more linkages selected from any of amide, imide, and urea moieties, present in any random order, and/or any combinations thereof;s, t, and u are integers independently ranging from 0 to 10; and,p is an integer ranging from 1 to about 500.12. (canceled)14. The composition of claim 13 , wherein R1 claim 13 , R2 claim 13 , R3 claim 13 , and R4 are H.15. A porous carbon composition that comprises monolithic carbon gels and/or ...

REMOVAL OF SOUR GASES FROM GAS MIXTURES CONTAINING THEM

There is an absorbent mixture usable for the removal of sour gases from gas mixtures. The mixture has at least one organic base having a pK(in water) less than or equal to 3.2; at least one alcoholic solvent of general formula R(OH)having a boiling temperature above or equal to 100° C. at ambient pressure, wherein R is a linear or branched saturated alkyl group having a number of carbon atoms between 2 and 20 and n is a whole number varying between 1 and 20; an aprotic polar solvent having a dielectric constant E at 25° C. greater than or equal to 30, a viscosity μ at 25° C. less than or equal to 14 cP, preferably less than or equal to 12 cP; and a boiling temperature at normal pressure equal to or above 130° C. There is also a process for the removal of sour gases using the absorbent mixture. 1. Absorbent mixture usable for removal of sour gases from gas mixtures containing them , comprising:{'sub': 'n', '#text': '(A) at least one alcohol of general formula R(OH)having a normal boiling point equal to or above 100° C., wherein R is an alkyl or alkylaromatic group, linear or branched, optionally substituted, having a number of carbon atoms between 2 and 20 and n is a whole number varying between 1 and 20;'}{'sub': 'b', '#text': '(B) at least one organic base having a pKof less than or equal to 3.2;'}(C) an aprotic polar solvent having a dielectric constant E at 25° C. greater than or equal to 30, a viscosity μ at 25° C. less than or equal to 14 cP, and a normal boiling point equal to or above 130° C.2. Absorbent mixture according to claim 1 , wherein the components A) claim 1 , B) and C) are present in the following proportions by weight:B/A comprised between 0.1 and 1.5;C/A comprised between 0.1 and 2.3. Absorbent mixture according to claim 1 , wherein the organic base B) has a pKcomprised between 0.3 and 3.0 and a boiling point above 100° C.4. Absorbent mixture according to claim 1 , wherein the organic base B) is a nitrogenated organic compound comprising from 5 ...

A system for flue-gas hydrate-based desalination using lng cold energy

A system for flue-gas hydrate-based desalination using LNG cold energy belongs to the field of hydrate technology application. The CO2 in the flue-gas is captured based on the hydrate formation. Two stage formation chambers are set to improve the hydrate formation. The two steps to purify the hydrates respectively are the gas separation and the liquid separation. The two methods of hydrate dissociation to realize the recycling of the waste heat of flue-gas and the CO2 are the heat-exchanged and the exhausted. The present invention realizes the integrated CO2 capture and seawater desalination with a proper structure and a subtle system and solves the cold energy source for hydrate-based desalination by means of using LNG cold energy. The two stage formation chambers solve the capture of CO2 in the flue-gas and guarantee the hydrate formation amounts. The two types of dissociation chambers decrease the heat emission by using the waste heat of flue-gas and realize the recycling and storage of CO2. The system will not be affected by the changes of seasons and environments and has a strong carrying capacity for the flue-gas source change. It is a system with great application value realistic.

Systems and Methods for Generating and Consuming Power from Natural Gas

Systems and methods are provided to mitigate flaring of natural gas. A natural gas processing system may process raw natural gas into a fuel gas stream that may be used to power any number of on-site power generation modules. In turn, the power generation modules may convert the fuel gas stream into an electrical output, which may be employed to power any number of distributed computing units housed within one or more mobile data centers. In certain embodiments, the distributed computing units may be adapted to mine cryptocurrency or perform other distributed computing tasks to generate revenue. 1. A flare mitigation system comprising: [ receive a fuel gas stream comprising a fuel gas associated with a heat value of at least about 1,000 Btu/scf; and', 'consume the fuel gas stream to generate a high-voltage electrical output associated with a first voltage; and, 'a power generation module adapted to, receive the high-voltage electrical output generated by the power generation module; and', 'transform the high-voltage electrical output into a low-voltage electrical output associated with a second voltage that is lower than the first voltage; and, 'an electrical transformation module in electrical communication with the power generation module, the electrical transformation module adapted to], 'an electrical power generation system comprising a communications system comprising one or more data satellite antennas, the communications system adapted to provide a network; and', an enclosure defining an interior space;', 'a plurality of distributed computing units located within the interior space of the enclosure, each of the plurality of distributed computing units in communication with the network; and', 'a power system located at least partially within the interior space of the enclosure, the power system in electrical communication with the electrical transformation module and the plurality of distributed computing units such that the power system receives the low- ...

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).

METHOD OF PREPARING NATURAL GAS AT A GAS PRESSURE REDUCTION STATIONS TO PRODUCE LIQUID NATURAL GAS (LNG)

A method to pre-treat an inlet natural gas stream at gas pressure reduction stations to produce LNG removes water and carbon dioxide from a natural gas stream. The energy required for the process is provided by recovering pressure energy in the inlet gas stream. The process eliminates the conventional gas pre-heating process at pressure reductions stations employing gas combustion heaters. The process provides a method to produce LNG at natural gas pressure reduction that meets product specifications. 1. A method of producing liquid natural gas (LNG) at gas pressure reduction stations , the gas pressure reduction station receiving a high pressure gas as an input and outputting a low pressure gas at an output pressure and temperature range , the method comprising the steps of:producing a hydrate inhibited stream by mixing a hydrate inhibitor with at least a portion of the high pressure gas; cooling the hydrate inhibited stream to produce a liquid phase, at least a portion of which comprises water, and separating the liquid phase from the hydrate inhibited stream; and', 'removing carbon dioxide using a carbon dioxide stripping agent;, 'producing a dehydrated gas stream bycondensing the dehydrated gas stream to produce a liquid stream of natural gas and a vapour stream of natural gas; andoutputting the vapour stream as the low pressure gas.2. The method of claim 1 , wherein at least one of the hydrate inhibitor and the carbon dioxide stripping agent is methanol.3. The method of claim 2 , wherein the hydrate inhibitor and the carbon dioxide stripping agent are methanol claim 2 , the methanol being recovered from the dehydrated gas stream and further comprising the step of recycling the methanol by separating the water and carbon dioxide from the methanol.4. The method of claim 1 , wherein outputting the vapour stream as the low pressure gas comprises adjusting the temperature and pressure to fall within the output pressure and temperature range.5. The method of claim 1 ...

CARBON DIOXIDE ABSORBENT AND METHOD OF USING THE SAME

In accordance with one aspect, the present invention provides a composition which contains the amino-siloxane structures I, or III, as described herein. The composition is useful for the capture of carbon dioxide from process streams. In addition, the present invention provides methods of preparing the amino-siloxane composition. Another aspect of the present invention provides methods for reducing the amount of carbon dioxide in a process stream employing the amino-siloxane compositions of the invention, as species which react with carbon dioxide to form an adduct with carbon dioxide. 2. The method according to claim 1 , wherein the amino-siloxane is a liquid.3. The method according to claim 1 , wherein said process stream is at least one selected from the group consisting of a combustion process claim 1 , a gasification process claim 1 , a landfill claim 1 , a furnace claim 1 , a steam generator claim 1 , and a boiler.4. The method according to claim 1 , wherein said process stream is a fuel stream.5. The method according to claim 4 , wherein said fuel stream comprises natural gas.6. The method according to claim 4 , wherein said fuel stream comprises syn gas. This application is a Divisional application of Ser. No. 12/817,276, filed on Jun. 17, 2010, the contents of which are incorporated herein by reference.This invention was made with Government support under grant number DE-NT0005310 awarded by the Department of Energy-NETL. The Government has certain rights in the invention.The invention relates to amino-siloxane compositions and their use as carbon dioxide absorbent materials.Pulverized coal power plants currently produce over half the electricity used in the United States. In 2007, these plants emitted over 1900 million metric tons of carbon dioxide (CO), and as such, accounted for 83% of the total COemissions from electric power generating plants and 33% of the total U.S. COemissions. Eliminating, or even reducing these emissions, will be essential in any ...

Membrane permeation treatment with adjustment of the temperature of the first retentate as a function of the ch4 concentration in the third and/or fourth permeate

A facility and method for membrane permeation treatment of a feed gas flow containing at least methane and carbon dioxide that includes a compressor, a pressure measurement device, at least one valve, and first, second, third, and fourth membrane separation units for separation of CO 2 from CH 4 to permeates enriched in CO 2 and retentates enriched in CH 4 , respectively. A temperature of the first retentate is adjusted at an inlet of the second membrane separation unit with at least one heat exchanger as a function of the measured CH 4 concentration in such a way so as to reduce the determined difference.

CHEMICALLY AND UV CROSS-LINKED HIGH SELECTIVITY POLYIMIDE MEMBRANES FOR GAS SEPARATIONS

This invention discloses a membrane composition, a method of making, and applications for a new type of high selectivity, high plasticization-resistant and solvent-resistant, both chemically and UV cross-linked polyimide membranes. Gas permeation tests on these membranes demonstrated that they not only showed high selectivities, but also showed extremely high COplasticization resistance under COpressure up to 4923 kPa (700 psig). This new type of high selectivity, high plasticization-resistant and solvent-resistant, both chemically and UV cross-linked polyimide membranes can be used for a wide range of gas separations such as separations of H/CH, He/CH, CO/CH, CO/N, olefin/paraffin separations (e.g. propylene/propane separation), O/N, iso/normal paraffins, polar molecules such as HO, HS, and NHmixtures with CH, N, H, and other light gases separations. The membranes can also be used for liquid separations such as in the removal of organic compounds from water. 5. A polyimide polymer membrane comprising the polyimide polymer of .6. The polyimide polymer membrane of is chemically and UV cross-linked.7. The polyimide polymer membrane of comprising a thin nonporous selective separation layer formed from the polyimide polymer with a plurality of repeating units of formula (I) and a porous nonselective mechanical support layer made from a material different from the polyimide polymer with a plurality of repeating units of formula (I).8. The polyimide polymer membrane of wherein said thin nonporous selective separation layer formed from the polyimide polymer with a plurality of repeating units of formula (I) is chemically and UV cross-linked.9. The polyimide polymer membrane of wherein said material different from the polyimide polymer with a plurality of repeating units of formula (I) is selected from the group consisting of polysulfones claim 7 , sulfonated polysulfones claim 7 , polyethersulfones (PESs) claim 7 , sulfonated PESs claim 7 , polyethers claim 7 , ...

COMPOSITES FOR CARBON DIOXIDE CAPTURE

Composite materials and methods of preparing C0capture include: (1) a porous solid support comprising a plurality of porous channels; and (2) a nucleophilic source associated with the porous channels of the porous solid support. The nucleophilic source is capable of converting the captured C0to poly(C0). Methods of capturing C0from an environment include associating the environment with the aforementioned composite materials to lead to the capture of C0from the environment. Such methods may also include a step of releasing the captured C0from the composite material. The associating step comprises a conversion of the captured C0to poly(C0) in the composite material. A releasing step may also include a depolymerization of the formed poly(C0). 1. A composite material for COcapture , comprising:a porous solid support comprising a plurality of porous channels; and 'wherein the nucleophilic source is at least associated with the porous channels of the porous solid support.', 'a nucleophilic source,'}2. The composite material of claim 1 , wherein the nucleophilic source is capable of converting COto poly(CO).3. The composite material of claim 1 , wherein the nucleophilic source is capable of converting COto poly(CO) at pressures that range from about 1 atm to about 100 atm.4. The composite material of claim 1 , wherein the porous solid support is selected from the group consisting of mesoporous carbon sources claim 1 , glass claim 1 , glass materials made from silicon oxide claim 1 , metals claim 1 , sulfur claim 1 , metal oxides claim 1 , metal nitrides claim 1 , metal sulfides claim 1 , metal selenides claim 1 , and combinations thereof.5. The composite material of claim 1 , wherein the porous solid support comprises one or more metals claim 1 , wherein the metals are selected from the group consisting of silicon claim 1 , boron claim 1 , calcium claim 1 , cobalt claim 1 , copper claim 1 , gold claim 1 , indium claim 1 , iron claim 1 , lead claim 1 , lithium claim 1 , ...

Imidazole-Containing Polymer Membranes and Methods of Use

Imidazole-containing polymer membranes are described herein. Methods of their preparation and use are also described herein. The methods of using the membranes include capturing and reducing volatile compounds from gas streams. 2. The method of claim 1 , wherein R is a vinyl-containing group claim 1 , an acrylate-containing group claim 1 , or a methacrylate-containing group.3. The method of claim 1 , wherein R is a substituted or unsubstituted styrene.4. The method of claim 3 , wherein the substituted styrene is α-methylstyrene.5. The method of claim 1 , wherein X claim 1 , Y claim 1 , and Z are all H.6. The method of claim 1 , wherein at least one of X claim 1 , Y claim 1 , and Z are selected from the group consisting of Calkyl and amino.7. The method of claim 1 , wherein at least one of X claim 1 , Y claim 1 , and Z are selected from the group consisting of halo claim 1 , nitro claim 1 , cyano claim 1 , or COCHgroups.8. The method of claim 1 , wherein Y and Z are combined to form a 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.9. The method of claim 1 , where the one or more additional monomers are used and are selected from the group consisting of divinylbenzene claim 1 , substituted or unsubstituted styrene claim 1 , acrylate claim 1 , methacrylate claim 1 , and methylmethacrylate.10. The method of claim 9 , wherein the substituted styrene is α-methylstyrene.11. The method of claim 1 , wherein the polymer membrane further comprises one or more metal cations.12. The method of claim 1 , wherein the gas stream is a flue gas or post-combustion gas stream.13. The method of claim 1 , wherein the polymer ...

Systems and Methods for Generating and Consuming Power from Natural Gas

Systems and methods are provided to mitigate flaring of natural gas. A natural gas processing system may process raw natural gas into a fuel gas stream that may be used to power any number of on-site power generation modules. In turn, the power generation modules may convert the fuel gas stream into an electrical output, which may be employed to power any number of distributed computing units housed within one or more mobile data centers. In certain embodiments, the distributed computing units may be adapted to mine cryptocurrency or perform other distributed computing tasks to generate revenue. 1. A method comprising:receiving a fuel gas stream comprising a fuel gas associated with a gas profile, the fuel gas having a heat value of at least about 1,000 Btu/scf; andgenerating, from the fuel gas stream, a high-voltage electrical output associated with a first voltage; andtransforming the high-voltage electrical output into a low-voltage electrical output associated with a second voltage that is lower than the first voltage;powering, via the low-voltage electrical output, a plurality of distributed computing units;monitoring the gas profile of the received fuel gas; andupon determining a change in the gas profile, modulating an electrical load of the plurality of distributed computing units.2. A method according to claim 1 , wherein:the high-voltage electrical output is from about 70 kW to about 2 MW; andthe first voltage is from about 480 V to about 4.16 kV.3. A method according to claim 2 , wherein the second voltage is from about 208 V to about 240 V.4. A method according to claim 1 , wherein the plurality of distributed computing units comprises at least about 200 distributed computing units.5. A method according to claim 4 , wherein said generating comprises consuming from about 50 Mscf to about 100 Mscf of fuel gas per day.6. A method according to claim 1 , wherein:the high-voltage electrical output is from about 1 MW to about 2 MW;the first voltage is about 480 ...

ARRANGEMENT FOR REGULATION OF A PLANT FOR THE MEMBRANE PERMEATION TREATMENT OF BIOGAS

Arrangement for regulation of a plant I for the membrane permeation treatment of a feed gas stream, comprising at least methane and carbon dioxide, that includes at least one means A for measurement of the gross calorific value (GCV) of the feed gas stream, at least one means B for comparison of the gross calorific value with a setpoint value E, at least one means C for production of a control signal as a function of the comparison of the gross calorific value with the setpoint value E, and at least one means D for transmission of this control signal to a means for regulation of said plant I. 1. An arrangement for regulation of a plant I for the membrane permeation treatment of a feed gas stream comprising at least methane and carbon dioxide , said arrangement comprising:at least one means A for measurement of the gross calorific value (GCV) of the feed gas stream;at least one means B for comparison of the gross calorific value with a setpoint value E;at least one means C for production of a control signal as a function of the comparison of the gross calorific value with the setpoint value E; andat least one means D for transmission of this control signal, wherein the means D is capable of transmitting the control signal to a means for regulation of said plant I or to a setpoint for concentration of methane or of carbon dioxide at the outlet of the plant in the form of a second setpoint value E′.2. The arrangement of claim 1 , wherein the means B and the means C are combined in a processor.3. The arrangement of claim 1 , wherein the means D for transmission of this control signal is capable of transmitting the control signal to a setpoint for concentration of methane or of carbon dioxide at the outlet of the plant in the form of a second setpoint value E′ and said arrangement comprises:at least one means A′ for measurement of the concentration of methane or of carbon dioxide at the outlet of the plant I,at least one means B′ for comparison of the concentration of ...

Apparatus and System for Swing Adsorption Processes Related Thereto

Provided are apparatus and systems for performing a swing adsorption process. This swing adsorption process may involve passing an input feed stream through two swing adsorption systems as a purge stream to remove contaminants, such as water, from the respective adsorbent bed units. The wet purge product stream is passed to a solvent based gas treating system, which forms a wet hydrocarbon rich stream and a wet acid gas stream. Then, the wet hydrocarbon rich stream and the wet acid gas stream are passed through one of the respective swing adsorption systems to remove some of the moisture from the respective wet streams. 1. A cyclical swing adsorption process for removing contaminants from a feed stream , the process comprising:a) performing one or more adsorption steps, wherein each of the adsorption steps comprises passing a feed stream from a solvent based gas treating system through a swing adsorption system to remove one or more contaminants from the feed stream and to form a product stream;b) performing one or more purge steps, wherein each of the purge steps comprises passing a purge stream through the swing adsorption system in a counter flow direction relative to the flow of the feed stream to form a purge product stream, wherein the purge product stream is passed to the solvent based gas treating system; andc) repeating the steps a) to b) for at least one additional cycle.2. The cyclical swing adsorption process of claim 1 , wherein the solvent based gas treating system separates one or more contaminants from the purge product stream to form a wet hydrocarbon rich stream and a wet acid gas stream.3. The cyclical swing adsorption process of claim 2 , wherein performing one or more adsorption steps comprises passing the wet hydrocarbon rich stream as the feed stream from the solvent based gas treating system through the adsorbent bed unit to remove water from the wet hydrocarbon rich stream and to form a dry wet hydrocarbon rich stream as the product stream.4 ...

Integration of Cold Solvent and Acid Gas Removal

A method of separating impurities from a natural gas stream. CO 2 and H 2 S are separated from the natural gas stream in a membrane separation system, thereby creating a partially-treated gas stream and a permeate gas stream, both of which are at a lower temperature than the natural gas stream. The partially-treated gas stream is contacted with a first lean solvent stream in a first contactor to separate H 2 S from the partially-treated gas stream, thereby producing a first rich solvent stream and a fully-treated gas stream. The permeate gas stream is contacted with a second lean solvent stream in a second contactor to separate H 2 S therefrom to produce a second rich solvent stream and a CO 2 gas stream. H 2 S and CO 2 are removed from the first and second rich solvent streams, thereby producing the first and second lean solvent streams.

PRESSURE-SWING ADSORPTION PROCESS FOR SEPARATING ACID GASES FROM NATURAL GAS

Disclosed are methods for removing acid gas from a feed stream of natural gas including acid gas, methane and ethane. The methods include alternating input of the feed stream between at least two beds of adsorbent particles comprising zeolite SSZ-13 such that the feed stream contacts one of the at least two beds at a given time in an adsorption step and a tail gas stream is simultaneously vented from another of the at least two beds in a desorption step. The contact occurs at a feed pressure of from about 50 to about 1000 psia for a sufficient period of time to preferentially adsorb acid gas from the feed stream. A product gas stream is produced containing no greater than about 2 mol % carbon dioxide and at least about 65 mol % of methane recovered from the feed stream and at least about 25 mol % of ethane recovered from the feed stream. The feed stream is input at a feed end of each bed. The product gas stream is removed from a product end of each bed. The tail gas stream is vented from the feed end of each bed. The methods require lower vacuum power consumption and allow improved hydrocarbon recoveries compared with known methods. 1. A method for removing acid gas from a feed gas stream of natural gas including acid gas , methane and ethane , comprising:alternating input of the feed gas stream between at least two beds of adsorbent particles comprising a zeolite of either SSZ-13 or some combination such that the feed gas stream contacts one of the at least two beds at a given time in an adsorption step and a tail gas stream is simultaneously vented from another of the at least two beds in a desorption step;wherein the contact occurs at a feed pressure of from about 50 to about 1000 psia for a sufficient period of time to preferentially adsorb acid gas from the feed gas stream; thereby producing a product gas stream containing no greater than about 2 mol % carbon dioxide and at least about 65 mol % of methane recovered from the feed gas stream and at least about 25 ...

Facility For Producing Gaseous Biomethane By Purifying Biogas From Landfill Combining Membranes, Cryodistillation And Deoxo

A process and facility for producing gaseous methane by purifying biogas from landfill can include a VOC purification unit, at least one membrane, a CO2 purification unit, a cryodistillation unit comprising a heat exchanger and a distillation column, a deoxo, and a dryer.

Apparatus and System For Swing Adsorption Processes Related Thereto

Provided are apparatus and systems for performing a swing adsorption process. This swing adsorption process may involve passing streams through adsorbent bed units to remove contaminants, such as water, from the stream. As part of the process, the adsorbent bed unit is purged with a purge stream that is provided from the overhead of the demethanizer. The configuration integrates a RCTSA dehydration system with a cryogenic recovery system. 1. A cyclical swing adsorption process for removing contaminants from a gaseous feed stream , the process comprising:a) performing one or more adsorption steps, wherein each of the adsorption steps comprises passing a gaseous feed stream at a feed pressure and feed temperature through an adsorbent bed unit to remove one or more contaminants from the gaseous feed stream and to form a product stream that is passed to a cryogenic recovery system including a demethanizer;b) performing one or more purge steps, wherein each of the purge steps comprises passing a purge stream through the adsorbent bed unit in a counter flow direction relative to the flow of the gaseous feed stream to form a purge product stream, wherein the purge stream comprises at least a portion of a demethanizer overhead stream from the demethanizer, wherein the purge pressure is in the range between 40% equal to or less than the feed pressure and 40% equal to or greater than the feed pressure; andc) repeating the steps a) to b) for at least one additional cycle.2. The cyclical swing adsorption process of claim 1 , wherein the purge stream comprises at least 20 volume % of the demethanizer overhead stream.3. The cyclical swing adsorption process of claim 1 , wherein the purge stream comprises at least 50 volume % of the demethanizer overhead stream.4. The cyclical swing adsorption process of claim 1 , wherein the purge stream comprises at least 95 volume % of the demethanizer overhead stream.5. The cyclical swing adsorption process of claim 1 , further comprising ...

GAS DESORPTION

The invention relates to a gas desorption unit and a process for desorbing gas absorbed in an absorption liquid, and a gas separation process. A gas desorption unit, comprising an assembly of plates, wherein plates comprise a corrugated part comprising ridges and valleys, and a first channel there between, adapted for counter-current flow of said gaseous and liquid stream in said first channel, and a said second channel for a liquid stream in counter-current flow with the liquid stream in the first channel, wherein a first channel comprises a corrugated part of a first plate comprising ridges crossing with ridges of the corrugated part of a second plate, and wherein a second channel comprises ridges of a corrugated part of a second plate comprising ridges aligned with valleys of a corrugated part of a third plate. 1. A gas desorption unit comprising an assembly of plates , said assembly comprising a first , second and third plate , each plate comprising a corrugated part comprising ridges and valleys , the corrugated parts of the first and second plate defining a part of a first channel between them , the corrugated parts of the second and third channel defining between them a part of a second channel adjacent to said part of said first channel ,wherein each of the first, second and third plate has opposed lateral ends, wherein the first channel comprises an inlet and an outlet for a gaseous stream at opposed lateral ends and an inlet and an outlet at opposed lateral ends for a liquid stream in counter-current flow with said gaseous stream, andwherein said second channel comprises an inlet and an outlet at opposed lateral ends for a liquid stream in counter-current flow with the liquid stream in the first channel,wherein the first channel comprises a corrugated part of the first plate comprising ridges crossing with ridges of the corrugated part of the second plate, and wherein the second channel comprises ridges of a corrugated part of the second plate comprising ...

RECOVERY AND RE-USE OF WASTE ENERGY IN INDUSTRIAL FACILITIES

Configurations and related processing schemes of direct or indirect (or both) inter-plants heating systems synthesized for grassroots medium grade crude oil semi-conversion refineries to increase energy efficiency from specific portions of low grade waste heat sources are described. Configurations and related processing schemes of direct or indirect (or both) inter-plants heating systems synthesized for integrated medium grade crude oil semi-conversion refineries and aromatics complex for increasing energy efficiency from specific portions of low grade waste sources are also described. 1. A method implemented in a crude oil refining facility , the method comprising:in a crude oil refining facility comprising a plurality of oil refining plants, each oil refining plant configured to perform at least one oil refining process, each oil refining plant comprising a plurality of interconnected oil refining sub-systems, wherein a plurality of streams at respective temperatures flow between the plurality of oil refining sub-systems:flowing a hydrocracking plant stream, a low temperature shift (LTS) converter product stream and a diesel hydro-treating plant stream of a hydrocracking plant, a hydrogen plant and a diesel hydro-treating plant, respectively, of the plurality of oil refining plants to one or more heat exchangers;flowing a stream from a first oil refining plant of the plurality of oil refining plants, the first oil refining plant being different from the hydrocracking plant, the hydrogen plant and the diesel hydro-treating plant, to the one or more heat exchangers, wherein the one or more heat exchangers transfer heat from one or more of the hydrocracking plant stream, the low temperature shift (LTS) converter product stream and the diesel hydro-treating plant stream to the stream from the first oil refining plant; andutilizing the stream from the first oil refining plant heated by one or more of the hydrocracking plant stream, the low temperature shift (LTS) ...

RECOVERY AND RE-USE OF WASTE ENERGY IN INDUSTRIAL FACILITIES

Configurations and related processing schemes of inter-plants and hybrid, intra- and inter-plants' direct or indirect heating systems synthesized for grassroots medium grade crude oil semi-conversion refineries to increase energy efficiency from specific portions of low grade waste heat sources are described. Configurations and related processing schemes of inter-plants and hybrid, intra- and inter-plants' direct or indirect heating systems synthesized for integrated medium grade crude oil semi-conversion refineries and aromatics complex for increasing energy efficiency from specific portions of low grade waste sources are also described. 1. A method implemented in a crude oil refining facility , the method comprising: flowing an aromatics plant stream in an aromatics plant of the plurality of oil refining plants to a first heat exchanger;', 'flowing a stream from a first oil refining plant of the plurality of oil refining plants, the first oil refining plant being different from the aromatics plant, to the first heat exchanger, wherein the first heat exchanger transfers heat from the aromatics plant stream to the stream from the first oil refining plant; and', 'utilizing the stream from the first oil refining plant heated by the aromatics plant stream in an oil refining process at the first oil refining plant., 'in a crude oil refining facility comprising a plurality of oil refining plants, each oil refining plant configured to perform at least one oil refining process, each oil refining plant comprising a plurality of interconnected oil refining sub-systems, wherein a plurality of streams at respective temperatures flow between the plurality of oil refining sub-systems2. The method of claim 1 , wherein the aromatics plant comprises a plurality of aromatics plant sub-units comprising an aromatics complex xylene products separation unit and a benzene extraction unit claim 1 , and wherein the plurality of oil refining plants comprise a sulfur recovery plant claim 1 , ...

RECOVERY AND RE-USE OF WASTE ENERGY IN INDUSTRIAL FACILITIES

Configurations and related processing schemes of specific inter-plants and hybrid, intra- and inter-plants waste heat recovery schemes for thermal energy consumption reduction in integrated refining-petrochemical facilities synthesized for grassroots medium grade crude oil semi-conversion refineries to increase energy efficiency from specific portions of low grade waste heat sources are described. Configurations and related processing schemes of specific inter-plants and hybrid, intra- and inter-plants waste heat recovery schemes for thermal energy consumption reduction in integrated refining-petrochemical facilities synthesized for integrated medium grade crude oil semi-conversion refineries and aromatics complex for increasing energy efficiency from specific portions of low grade waste sources are also described. 1. A method implemented in a crude oil refining facility , the method comprising:heating a first plurality of streams in a first plurality of plants in a crude oil facility using a second plurality of streams in a second plurality of plants in the crude oil refining facility using a plurality of heat exchangers that receive at least one of the first plurality of streams and at least one of the second plurality of streams.2. A method implemented in a crude oil refining facility , the method comprising:heating a first plurality of streams in a first plurality of plants in a crude oil facility using a second plurality of streams in a second plurality of plants in the crude oil refining facility using a plurality of heat exchangers that receive at least one of the first plurality of streams and at least one of the second plurality of streams, wherein the first plurality of plants comprises an amine regeneration plant, an aromatics complex benzene extraction unit, a sour water stripper plant, a sulfur recovery plant, a gas separation plant, and wherein the second plurality of plants comprises an aromatics plant xylene products separation unit, a hydrocracking ...

CROSSLINKED POLYMERIC BLENDED MEMBRANES FOR GAS SEPARATION

Methods of making a gas separation membrane, a gas separation membrane, and method of gas separation. The gas separation membrane includes cross-linked poly(ether-b-amide) copolymer, in which the poly(ether-b-amide) copolymer comprise urethane crosslinks which is the reaction product of poly(ether-b-amide) copolymer and diisocyanate polyether according to formula (I): 2. The method of making a gas separation membrane of claim 1 , in which the poly(ether-b-amide) copolymer comprises a 25 to 80% by weight polyether segment and a 75 to 20% by weight polyamide segment.3. The method of making a gas separation membrane of claim 1 , in which Ris methyl or —H.4. The method of making a gas separation membrane of claim 1 , in which Rand Rare −C═N═O; and Rand Rare methyl.5. The method of making a gas separation membrane of claim 1 , in which the polymer solution comprises 1 to 99 weight percent of poly(ether-b-amide) copolymer.6. The method of making a gas separation membrane of claim 1 , in which the cros slinking solution comprises 2 to 40 weight percent of the crosslinker according to formula (I).7. The method of making a gas separation membrane of claim 1 , in which the cros slinking solution had a temperature of from 35 to 85° C.8. The method of making a gas separation membrane of claim 1 , in which the gas separation membrane was dried at a temperature of from 35 to 90° C.10. (canceled)12. The gas separation membrane according to claim 11 , in which the gas separation membrane further comprises a thickness of from 30 to 70 micrometers (μm).13. The gas separation membrane according to claim 11 , in which Ris methyl or —H.14. The gas separation membrane according to claim 11 , in which Rand Rare —C═N═O; and Rand Rare methyl.15. The gas separation membrane according to claim 11 , in which the gas separation membrane further comprises 1 to 99% by weight of poly(ether-b-amide) copolymer.16. The gas separation membrane according to claim 11 , in which the gas separation ...

Overcoming two carbon dioxide adsorption steps in diamine-appended metal-organic frameworks

Primary, secondary (1º,2º) alkylethylenediamine- and alkylpropylenediamine-appended variants of metal-organic framework are provided for CO2 capture applications. Increasing the size of the alkyl group on the secondary amine enhances the stability to diamine volatilization from the metal sites. Two-step adsorption/desorption profiles are overcome by minimizing steric interactions between adjacent ammonium carbamate chains. For instance, the isoreticularly expanded framework Mg2(dotpdc) (dotpdc4−=4,4″-dioxido-[1,1′:4′,1″-terphenyl]-3,3″-dicarboxylate), yields diamine-appended adsorbents displaying a single CO2 adsorption step. Further, use of the isomeric framework Mg-IRMOF-74-II or Mg2(pc-dobpdc) (pc-dobpdc4−=3,3-dioxidobiphenyl-4,4-dicarboxylate, pc=para-carboxylate) also leads to a single CO2 adsorption step with bulky diamines. By relieving steric interactions between adjacent ammonium carbamate chains, these frameworks enable step-shaped CO2 adsorption, decreased water co-adsorption, and increased stability to diamine loss. Variants of Mg2(dotpdc) and Mg2(pc-dobpdc) functionalized with large diamines such as N-(n-heptyl)ethylenediamine have utility as adsorbents for carbon capture applications.

Removing Impurities From A Gas Stream

A co-current contacting system for removing impurities from a gas stream is described herein. The co-current contacting system includes a co-current contactor configured to co-currently flow a gas stream including impurities and a liquid stream through the co-current contactor. The co-current contactor is also configured to incorporate liquid droplets formed from the liquid stream into the gas stream, such that the impurities from the gas stream are absorbed by the liquid droplets. The co-current contacting system also includes a separator configured to remove the gas stream from the liquid droplets including the impurities, generating a purified gas stream and a rich liquid stream. The co-current contacting system is configured to recycle the rich liquid stream for reuse as a portion of the liquid stream flowing into the co-current contactor. 1. A co-current contacting system for removing impurities from a gas stream , comprising: co-currently flow the gas stream comprising impurities and a liquid stream through the co-current contactor; and', 'incorporate liquid droplets formed from the liquid stream into the gas stream, such that the impurities from the gas stream are absorbed by the liquid droplets; and, 'a co-current contactor configured toa separator configured to remove the gas stream from the liquid droplets comprising the impurities, generating a purified gas stream and a rich liquid stream; andwherein the co-current contacting system is configured to recycle the rich liquid stream for reuse as a portion of the liquid stream flowing into the co-current contactor.2. The co-current contacting system of claim 1 , wherein the co-current contactor is located in-line within a pipe claim 1 , and wherein the co-current contactor comprises:an annular support ring configured to maintain the co-current contactor within the pipe;a plurality of radial blades configured to allow the liquid stream to flow into the co-current contactor; anda central gas entry cone ...

Method for Electrical Energy Storage with Co-production of Liquefied Methaneous Gas

A method for electrical energy storage with co-production of liquefied methaneous gas which comprises in combination the processes of charging the storage with liquid air through its production using an externally powered compressor train and open air auto-refrigeration cycle, storing the produced liquid air and discharging the storage through pumping, regasifying, superheating and expanding the stored air with production of on-demand power, and additionally includes a process of recovering the cold thermal energy released by regasified liquid air for controlled liquefying the methaneous gas delivered into energy storage facility at a rate and pressure consistent with those of liquid air. 1. A method for electrical energy storage with co-production of liquefied methaneous gas (LMG) , comprising in combination:{'sub': 2', '2, 'charging the energy storage including the steps of externally powered compressing the fresh air stream up to a bottom charge pressure with its further freeing from the COand HO contaminants, mixing the streams of treated fresh and recirculating air streams at a bottom charge pressure thus forming a process air stream, succeeding externally powered compressing the process air up to a rated charge pressure and its final self-powered compressing up to a top charge pressure and processing between the top and bottom charge pressures in the turbo expander-compressor based open air auto-refrigeration cycle, resulting in generating a liquefied air from a part of process air at a bottom charge pressure and recirculating a rest of it for mixing with a fresh air;'}storing the produced liquid air between the energy storage charge and discharge;discharging the storage including the processes of pumping the liquid air at a top discharge pressure, capturing a cold thermal energy from liquid air resulting in its re-gasifying, further thermally assisted air superheating and its at least one-stage expanding down to bottom discharge pressure with on-demand ...

RECOVERY AND RE-USE OF WASTE ENERGY IN INDUSTRIAL FACILITIES

Configurations and related processing schemes of direct or indirect (or both) inter-plants heating systems synthesized for grassroots medium grade crude oil semi-conversion refineries to increase energy efficiency from specific portions of low grade waste heat sources are described. Configurations and related processing schemes of direct or indirect (or both) inter-plants heating systems synthesized for integrated medium grade crude oil semi-conversion refineries and aromatics complex for increasing energy efficiency from specific portions of low grade waste sources are also described. 1. A system implemented in a crude oil refining facility comprising a plurality of oil refining plants , each oil refining plant configured to perform at least one oil refining process , each oil refining plant comprising a plurality of interconnected oil refining sub-systems , wherein a plurality of streams at respective temperatures flow between the plurality of oil refining sub-systems , the system comprising:a hydrocracking plant stream, a low temperature shift (LTS) converter product stream and a diesel hydro-treating plant stream of a hydrocracking plant, a hydrogen plant and a diesel hydro-treating plant, respectively, of the plurality of oil refining plants;a stream from a first oil refining plant of the plurality of oil refining plants, the first oil refining plant being different from the hydrocracking plant, the hydrogen plant and the diesel hydro-treating plant; andone or more heat exchangers configured to transfer heat from one or more of the hydrocracking plant stream, the low temperature shift (LTS) converter product stream and the diesel hydro-treating plant stream to the stream from the first oil refining plant.2. The system of claim 1 , wherein the first oil refining plant comprises a naphtha hydro-treating plant claim 1 , a sour water stripper plant claim 1 , an amine regeneration plant separation section claim 1 , a sulfur recovery plant and a gas separation plant. ...

RECOVERY AND RE-USE OF WASTE ENERGY IN INDUSTRIAL FACILITIES

Configurations and related processing schemes of direct or indirect inter-plants heating systems (or both) synthesized for grassroots medium grade crude oil semi-conversion refineries to increase energy efficiency from specific portions of low grade waste heat sources are described. Configurations and related processing schemes of direct or indirect inter-plants heating systems (or both) synthesized for integrated medium grade crude oil semi-conversion refineries and aromatics complex for increasing energy efficiency from specific portions of low grade waste sources are also described. 1. A system implemented in a crude oil refining facility comprising a plurality of oil refining plants , each oil refining plant configured to perform at least one oil refining process , each oil refining plant comprising a plurality of interconnected oil refining sub-systems , wherein a plurality of streams at respective temperatures flow between the plurality of oil refining sub-systems , the system comprising:a diesel hydro-treating plant stream from a diesel hydro-treating plant of the plurality of oil refining plants to a first heat exchanger;a stream from a first oil refining plant of the plurality of oil refining plants, the first oil refining plant being different from the diesel hydro-treating plant; anda first heat exchanger configured to transfer heat from the diesel hydro-treating plant stream to the stream from the first oil refining plant.2. The system of claim 1 , wherein the first oil refining plant is a sulfur recovery plant claim 1 , the stream is a sulfur recovery plant stream claim 1 , and the system further comprises:an oil refinery gas separation plant stream in an oil refinery gas separation plant of the plurality of oil refining plants; anda second heat exchanger configured to heat the oil refinery gas separation plant stream using the heated sulfur recovery plant stream.31. The system of claim 1 , wherein the sulfur recovery plant stream comprises an amine ...

Methods for Methane Purification

Ancillary embodiments and modifications to a homogenizer unit (“PPH”), and methods of use directed to purification of biogas or other raw methane streams. The apparatus includes a homogenizer body, one or more stream inlets (for the raw methane), one or more chilled water inlets, a mixing zone where the water stream is commingled with the raw methane stream, and a venturi immediately downstream from the mixing zone such that the commingled streams are pulled into the venturi resulting in homogenization. The PPH components are insulated to maintain the chilled water of the various streams at a cooled, below ambient temperature, increasing dissolution of the contaminant gases into the chilled water, and producing a purified methane stream including little or no HS and CO. 1. A method for purifying a methane containing stream , the method comprising:introducing a raw methane stream into a mixing zone through an inlet, the raw methane stream including methane and one or more contaminants selected from the group consisting of carbon dioxide, ammonia, hydrogen sulfide and combinations thereof;introducing a water stream into the mixing zone through a separate water inlet such that the water stream is commingled with the raw methane stream upon both streams entering the mixing zone;passing the commingled streams through a venturi so as to homogenize the streams such that one or more contaminants within the raw methane stream are dispersed within the water stream, forming a contaminant isolation stream including the one or more contaminants and a purified methane stream;wherein the water stream is chilled to below ambient temperature to increase dissolution of the one or more contaminants therein.2. A method as recited in claim 1 , wherein the raw methane stream includes carbon dioxide claim 1 , the carbon dioxide dissolving into the chilled water stream claim 1 , so as to remove the carbon dioxide from the raw methane stream claim 1 , the method further comprising capturing ...

METHOD FOR SMOOTHING TIME-VARYING CONCENTRATION OF A FLUID STREAM

A process for reducing the size of sulfur removal units is presented. The process includes passing a regeneration gas from a regenerated contaminant adsorption unit through a fixed bed adsorber. The fixed bed adsorber adsorbs sulfur compounds above an equilibrium condition and releases adsorbed sulfur compounds below the equilibrium condition. The peak levels of sulfur in the regeneration gas are reduced and the processing of the regeneration gas reduces the size of sulfur removal units. 1. A process for removing sulfur compounds from a natural gas stream comprising:passing a natural gas feed stream to an acid gas removal unit to generate a partially sweetened natural gas stream and an acid gas stream;passing the partially sweetened natural gas stream to an adsorption unit for adsorbing water and sulfur compounds to generate a treated natural gas stream;passing a regenerator gas stream to the adsorption unit to generate a regen gas enriched with sulfur compounds;passing the regen gas enriched with sulfur compounds to a fixed-bed adsorber to generate a regen gas effluent stream with a reduced level of peak sulfur concentration; andpassing the regen gas with the reduced level of peak sulfur compounds to a sulfur removal unit.2. The process of wherein the fixed-bed adsorber adsorbs sulfur compounds from the regen gas above an equilibrium adsorption concentration claim 1 , and desorbs sulfur compounds from the adsorbent below the equilibrium adsorption concentration.3. The process of wherein the fixed-bed adsorber adsorbs hydrocarbon compounds from the regen gas above an equilibrium adsorption concentration claim 1 , and desorbs hydrocarbon compounds from the adsorbent below the equilibrium adsorption concentration.4. The process of further comprising passing the treated natural gas stream to a natural gas liquids recovery unit to generate a treated gas stream claim 1 , a C2 stream claim 1 , a C3 stream claim 1 , and a C4 stream.5. The process of further comprising: ...

Process for separation and purification of renewable propane

A method for treating a gas stream comprising hydrogen and propane, where a combination of membrane separation and elevated pressure distillation is used to separate the hydrogen gas from the propane gas.

NOVEL BETA-HYDROXYLATED TERTIARY DIAMINES, A PROCESS FOR THEIR SYNTHESIS AND THEIR USE FOR ELIMINATING ACID COMPOUNDS A GASEOUS EFFLUENT

The invention relates to novel nitrogen compounds belonging to the family of tertiary diamines of general formula (I) below, wherein R is an alkanediyl radical —(CH)n- with n=2, 3, 4, 5 or 6. 4. A synthesis method of a nitrogen compound as claimed in claim 1 , comprising the following reactions:a first reaction of epoxidation of an alpha-omega-diene to achieve epoxidation of each one of the alkene functions of the alpha-omega-diene to oxirane functions so as to produce a diepoxyalkane,{'claim-ref': {'@idref': 'CLM-00001', 'claim 1'}, 'a second reaction of addition of two moles of dimethylamine and one molecule of the diepoxyalkane so as to produce the nitrogen compound as claimed in .'}5. A method as claimed in claim 4 , wherein:the first reaction is an epoxidation reaction of 1,5-hexadiene to produce 1,2,5,6-diepoxyhexane,the second reaction is an addition reaction of two moles of dimethylamine and one molecule of 1,2,5,6-diepoxyhexane to produce N,N,N′,N′-(tetramethyl)-1,6-diamino-2,5-hexanediol.6. A method as claimed in claim 4 , wherein:the first reaction is an epoxidation reaction of 1,7-octadiene to produce 1,2,7,8-diepoxyoctane,the second reaction is an addition reaction of two moles of dimethylamine and one molecule of 1,2,7,8-diepoxyoctane to produce N,N,N′,N′-(tetramethyl)-1,8-diamino-2,7-octanediol.7. A method as claimed in claim 4 , wherein the first epoxidation reaction consists in reacting the alpha-omega-diene with a peracid or a peroxide or a hydroperoxide or oxygen associated with a suitable catalytic system claim 4 , and said peracid can be generated in situ by reaction between a carboxylic acid and a hydrogen peroxide.8. A method as claimed in claim 4 , wherein the second addition reaction is carried out in the presence of excess dimethylamine.9. A method as claimed in claim 4 , wherein the first epoxidation reaction and the second addition reaction are carried out in two successive stages.10. A method of removing acid compounds contained in a ...

GAS SEPARATION BY VAPORIZED COMPOUND

An improved process for deacidizing a gaseous mixture with reduced overall energy costs is described. The process involves contacting the gaseous mixture with at least one of a vaporizing compound, a vaporized compound, a vaporizing solution of compound and a vaporized solution of compound, and forming a liquid or solid reaction product that can be easily separated from the gaseous mixture. 1. A method for deacidizing a gas stream comprising one or more acid gases , comprising:mixing a compound with the gas stream, wherein the compound reacts with the one or more acid gases in the gas stream to form a reaction product in a gas phase;causing the reaction product to precipitate from the gas phase in a form of a liquid or a solid; andcollecting the liquid or the solid reaction product.2. The method of claim 1 , further comprising processing the liquid or the solid reaction product to release the compound from the reaction product.3. The method of claim 2 , further comprising mixing the released compound with the gas stream.4. The method of claim 1 , wherein the one or more acid gases are selected from the group consisting of carbon dioxide (CO) claim 1 , sulfur dioxide (SO) claim 1 , sulfur trioxide (SO) claim 1 , hydrogen sulfide (HS) claim 1 , carbon oxysulfide (COS) claim 1 , carbon disulfide (CS) claim 1 , mercaptans (RSH) claim 1 , nitric oxide (NO) claim 1 , nitric dioxide (NO) claim 1 , fluorides claim 1 , HCl claim 1 , and HF.5. The method of claim 1 , wherein the compound comprises an amine selected from the group consisting of monoethanolamine claim 1 , diethanolamine claim 1 , triethanolamine claim 1 , ethanolamines claim 1 , isopropanolamines claim 1 , ethyleneamines claim 1 , alkyl alkanolamines claim 1 , methyldiethanolamine claim 1 , piperidine claim 1 , piperazine claim 1 , dibutylamine claim 1 , diisopropylamine claim 1 , and a mixture thereof.6. The method of claim 1 , further comprising vaporizing the compound.7. The method of claim 6 , wherein the ...

IMPROVED ACID GAS REMOVAL PROCESS BY ABSORBENT SOLUTION COMPRISING AMINE COMPOUNDS

Disclosed is a process for deacidising a non-aqueous feed comprising one of HS, CO, COS, CS, disulphides and/or mercaptans, comprising 2. The method according to wherein the lean absorbent solution contains from 20 to 60% by weight of the absorbent.3. The method according to wherein the lean absorbent solution further comprises an accelerator for the reaction of the absorbent with at least one of the acid compounds.4. The method according to wherein the lean absorbent solution contains 0.5 to 40% by weight of the accelerator.5. The method according to wherein the accelerator is selected from the group consisting of amines claim 3 , alcohols claim 3 , ketones claim 3 , vinyl alcohols claim 3 , vinyl ketones claim 3 , ether alcohols claim 3 , ether ketones claim 3 , glycols claim 3 , polyethylene glycols claim 3 , polypropylene glycols claim 3 , ethylene glycolpropylene glycol copolymers claim 3 , glycol ethers claim 3 , thioglycols claim 3 , thioalcohols claim 3 , sulfones claim 3 , sulfoxide claim 3 , N-alkylated pyrrolidones claim 3 , N-alkylated piperidones claim 3 , cyclotetramethylenesulfones claim 3 , N-alkylformamides claim 3 , N-alkylacetamides claim 3 , alkyl phosphates claim 3 , alkylene carbonates and/or dialkyl carbonates claim 3 , and combinations or mixtures thereof claim 3 , preferably selected from monoethanol amine claim 3 , MEA claim 3 , diethanol amine claim 3 , DEA claim 3 , monomethyl ethanolamine claim 3 , MMEA claim 3 , piperazine claim 3 , 2-methylpiperazine claim 3 , N-methyl piperazine claim 3 , N-ethylpiperazine claim 3 , N-hydroxyethyl piperazine claim 3 , HEP claim 3 , N-(2-aminoethyl) piperazine claim 3 , homopiperazine claim 3 , piperidine and morpholine claim 3 , and mixtures thereof.66. The method according to wherein the absorbent solution () comprises a mixture of methyl diethanol amine claim 1 , MDEA claim 1 , with tris(N claim 1 ,N claim 1 ,-dimethylamino propyl)amine in a weight ratio in the range of at least 30:70.7. The method ...

PROCESS FOR INJECTING BIOMETHANE INTO A NATURAL GAS NETWORK

A process for injecting biomethane into a network which has a gross calorific value of value X between X1 and X2, comprising the injection of nitrogen into the biomethane network before the injection of the biomethane into the network which has a gross calorific value of value X so as to reduce the calorific value of the biomethane network to a value between X1 and X2, with the nitrogen derived from the retentate of at least one membrane stage. 112-. (canceled)13. A process for injecting biomethane into a biomethane network that has a gross calorific value of value X between X1 and X2 , comprising the steps of:injecting biomethane having a gross calorific value greater than X2 into a biomethane network; andinjecting nitrogen into the biomethane network in an amount sufficient to achieve an overall calorific value of the injected biomethane and nitrogen of between X1 and X2, wherein the nitrogen being injected is obtained from a retentate of at least one membrane stage.14. The process for injecting biomethane of claim 13 , wherein X1=9.5 kWh/Nmand X2=10.5 kWh/Nm.15. The process of claim 13 , further comprising the steps of:feeding, to the at least one membrane stage, air from an internal network of the process or from an air compressor;separating the fed air into an impure oxygen permeate and an impure nitrogen retentate, the impure nitrogen retentate being the nitrogen that is injected into the biomethane network; andcontrolling the amount of nitrogen injected into the biomethane network via a control valve located on a feed of the at least one membrane stage or via adjustment of a production capacity of the air compressor.16. The process of claim 15 , wherein upstream of the compressor the air is dried and de-oiled and is at a pressure greater than or equal to a pressure of the biomethane network.17. The process of claim 15 , wherein a purity of the nitrogen injected into the biomethane network is controlled based upon a concentration of oxygen in the impure ...

A DEVICE AND A MEMBRANE PROCESS FOR SEPARATING GAS COMPONENTS FROM A GAS STREAM HAVING VARYING COMPOSITION OR FLOW RATE

A device for separating a gas stream which has a compressor and three membrane separation units in series, connected to pass the retentate stream of each of the first two units to the subsequent membrane separation unit, comprises conduits for recycling the permeate streams of the second and the third membrane separation unit to upstream of the compressor and a control device controlling the fraction of the second permeate stream which is recycled. Adjusting which fraction of the second permeate is recycled can be used to maintain a target composition of the retentate obtained in the third membrane separation unit when the flow rate or the composition of the gas stream changes.

Systems and Methods for Generating and Consuming Power from Natural Gas

Systems and methods are provided to mitigate flaring of natural gas. A natural gas processing system may process raw natural gas into a fuel gas stream that may be used to power any number of on-site power generation modules. In turn, the power generation modules may convert the fuel gas stream into an electrical output, which may be employed to power any number of distributed computing units housed within one or more mobile data centers. In certain embodiments, the distributed computing units may be adapted to mine cryptocurrency or perform other distributed computing tasks to generate revenue.

Systems and Methods for Generating and Consuming Power from Natural Gas

Systems and methods are provided to mitigate flaring of natural gas. A natural gas processing system may process raw natural gas into a fuel gas stream that may be used to power any number of on-site power generation modules. In turn, the power generation modules may convert the fuel gas stream into an electrical output, which may be employed to power any number of distributed computing units housed within one or more mobile data centers. In certain embodiments, the distributed computing units may be adapted to mine cryptocurrency or perform other distributed computing tasks to generate revenue.

SYSTEM FOR, METHOD OF, AND THE RESULTING PRODUCT OF THE PRODUCTION OF FUEL GAS, HEAT AND ELECTRICITY AND THE CLEANING OF CARBON EMISSIONS

The field of present invention generally relates to furnaces that combine fuel production with both thermal and electrical energy production. They also are capable of using carbon emission as part of the production process. More particularly, the present invention produces a combustible gas that, within the internal workings of the present invention, can efficiently be burned at relatively lower temperatures and pressures without the production of high levels of pollutants. Further, the present invention can receive what are ordinarily wasteful carbon emissions for use in the production of more desirable outputs. The foregoing characteristics, along with the limited size of the elements needed to practice the present invention, make it conducive for use as and in connection with, among other things, residential furnaces and other heating systems, including, for example, heat exchangers and residential hot water tanks. In short, the present invention involves the production of a combustible fuel gas, and of thermal and electric energy, and the productive use of carbon emissions. This production is accomplished through the interconnected use of water electrolysis, catalysts, storage means, regulation, and mean of reusing materials to increase production efficiencies. 1. A method of efficiently producing a combustible gas , without producing polluting emissions from fossil hydrocarbons , comprising the steps ofa) producing primary gases by water electrolysis;b) mixing and filtering such primary gases;{'sub': '2', 'c) internally producing COgas using a voltage between 1 V [DC] and 240 V [DC] and 1V [AC] and 400 V [AC];'}{'sub': '2', 'd) storing such COgas;'}{'sub': '2', 'e) mixing the filtered primary gases with the previously produced COgas (and CO gas) in a catalytic reaction at a temperature above 15° C. and below 500° C. and at a pressure higher than 1 bar and lower than 10 bar wherein the gas mixture is conveyed over the surface of a desired catalyst;'}f) releasing ...

Systems and Methods for Generating and Consuming Power from Natural Gas

Systems and methods are provided to mitigate flaring of natural gas. A natural gas processing system may process raw natural gas into a fuel gas stream that may be used to power any number of on-site power generation modules. In turn, the power generation modules may convert the fuel gas stream into an electrical output, which may be employed to power any number of distributed computing units housed within one or more mobile data centers. In certain embodiments, the distributed computing units may be adapted to mine cryptocurrency or perform other distributed computing tasks to generate revenue. 1. A flare mitigation system comprising: [ [{'b': 1', '000, 'receive a fuel gas stream comprising a fuel gas associated with a heat value of at least about , Btu/scf; and'}, 'consume the fuel gas stream to generate a high-voltage electrical output associated with a first voltage; and, 'a power generation module adapted to, receive the high-voltage electrical output generated by the power generation module; and', 'transform the high-voltage electrical output into a low-voltage electrical output associated with a second voltage that is lower than the first voltage; and, 'an electrical transformation module in electrical communication with the power generation module, the electrical transformation module adapted to], 'an electrical power generation system comprising a communications system comprising one or more data satellite antennas, the communications system adapted to provide a network; and', an enclosure defining an interior space;', 'a plurality of distributed computing units located within the interior space of the enclosure, each of the plurality of distributed computing units in communication with the network; and', 'a power system located at least partially within the interior space of the enclosure, the power system in electrical communication with the electrical transformation module and the plurality of distributed computing units such that the power system ...

Systems for recovery and re-use of waste energy in crude oil refining and aromatics complex

Configurations and related processing schemes of specific inter-plants and hybrid, intra- and inter-plants waste heat recovery schemes for thermal energy consumption reduction in integrated refining-petrochemical facilities synthesized for grassroots medium grade crude oil semi-conversion refineries to increase energy efficiency from specific portions of low grade waste heat sources are described. Configurations and related processing schemes of specific inter-plants and hybrid, intra- and inter-plants waste heat recovery schemes for thermal energy consumption reduction in integrated refining-petrochemical facilities synthesized for integrated medium grade crude oil semi-conversion refineries and aromatics complex for increasing energy efficiency from specific portions of low grade waste sources are also described.

SYSTEMS FOR RECOVERY AND RE-USE OF WASTE ENERGY IN HYDROCRACKING-BASED CONFIGURATION FOR INTEGRATED CRUDE OIL REFINING AND AROMATICS COMPLEX

Configurations and related processing schemes of specific direct or indirect inter-plants integration for energy consumption reduction synthesized for grassroots medium grade crude oil semi-conversion refineries to increase energy efficiency from specific portions of low grade waste heat sources are described. Configurations and related processing schemes of specific direct or indirect inter-plants integration for energy consumption reduction for integrated medium grade crude oil semi-conversion refineries and aromatics complex for increasing energy efficiency from specific portions of low grade waste sources are also described. 1. A system comprising:a plurality of oil refining plants in a crude oil refining facility, each oil refining plant configured to perform at least one oil refining process, wherein a plurality of streams at respective temperatures flow between the plurality of oil refining plants; flow a first plurality of streams from a first subset of the plurality of oil refining plants to a plurality of heat exchangers, wherein the first subset comprises a naphtha hydrotreating plant, a gas separation plant, an amine regeneration plant, a sulfur recovery plant, a sour water stripper plant, and an aromatics plant which comprises an aromatics plant xylene products separation unit and an aromatics complex benzene extraction unit, wherein the plurality of first streams comprises a sulfur recovery plant amine regeneration unit stripper bottom stream in the sulfur recovery plant, a raffinate splitter bottoms stream in the aromatics complex benzene extraction unit, an acid gas regenerator bottoms stream in the amine regeneration plant, a sour water stripper bottoms stream in the sour water stripper plant, a benzene column bottoms stream in the aromatics complex benzene extraction unit, a C3/C4 stripper bottom stream in the gas separation plant, and a de-ethanizer bottoms stream in the gas separation plant, and', 'flow a second plurality of streams from a second ...

SYSTEMS FOR RECOVERY AND RE-USE OF WASTE ENERGY IN HYDROCRACKING-BASED CONFIGURATION FOR INTEGRATED CRUDE OIL REFINING AND AROMATICS COMPLEX

Configurations and related processing schemes of specific direct or indirect inter-plants integration for energy consumption reduction synthesized for grassroots medium grade crude oil semi-conversion refineries to increase energy efficiency from specific portions of low grade waste heat sources are described. Configurations and related processing schemes of specific direct or indirect inter-plants integration for energy consumption reduction for integrated medium grade crude oil semi-conversion refineries and aromatics complex for increasing energy efficiency from specific portions of low grade waste sources are also described. 1. A method implemented in a crude oil refining facility , the method comprising: flowing a first plurality of streams from a first subset of the plurality of oil refining plants to a plurality of heat exchangers;', 'flowing a second plurality of streams from a second subset of the plurality of oil refining plants to the plurality of heat exchangers, wherein the plurality of heat exchangers transfer heat from the first plurality of streams to the second plurality of streams; and', 'utilizing the heated second plurality of streams in one or more oil refining processes at the second subset of the plurality of oil refining plants., 'in a crude oil refining facility comprising a plurality of oil refining plants, each oil refining plant configured to perform at least one oil refining process, each oil refining plant comprising a plurality of interconnected oil refining sub-systems, wherein a plurality of streams at respective temperatures flow between the plurality of oil refining sub-systems2. The method of claim 1 , wherein the first subset comprises a naphtha hydrotreating plant claim 1 , a gas separation plant claim 1 , an amine regeneration plant claim 1 , a sulfur recovery plant claim 1 , a sour water stripper plant claim 1 , and an aromatics plant which comprises an aromatics plant xylene products separation unit and a aromatics column ...

Natural gas pretreatment system and method for pretreating natural gas

A natural gas pretreatment system includes: a carbon dioxide removal unit configured to remove carbon dioxide from the natural gas by bringing an absorption liquid and the natural gas into contact with each other; and a water removal unit configured to remove water by causing the natural gas to flow through a packed bed containing a water adsorbent. The packed bed contains a carbon dioxide adsorbent for adsorbing and removing the carbon dioxide that has not been completely removed in the carbon dioxide removal unit, and a concentration of the carbon dioxide contained in the natural gas is measured by an outlet-side carbon dioxide measurement unit on an outlet side of the water removal unit.

Grafted Polymer Nanocomposite Materials, Systems, And Methods

Provided are methods of separating one or more components from a fluid by using membranes and other materials comprising polymer graft nanoparticles arranged in a lattice structure. The disclosed compositions exhibit an increase in selectivity between two penetrants that is greater than the neat polymer selectivity for those penetrants. The compositions also exhibit an increase in selectivity between two penetrants with increasing permeability. Also provided are systems for effecting such separations, systems for agent detection, and additional methods for constructing separation components.

PROCESSES USING MOLECULAR SIEVE SSZ-96

The present disclosure is directed to processes using a new crystalline molecular sieve designated SSZ-96, which is synthesized using a 1-butyl-1-methyl-octahydroindolium cation as a structure directing agent. 2. The process of claim 1 , wherein the molecular sieve has a mole ratio of at least 10 of (1) silicon oxide to (2) and oxide selected from boron oxide claim 1 , aluminum oxide claim 1 , gallium oxide claim 1 , indium oxide claim 1 , and mixtures thereof.4. The process of claim 3 , wherein T is selected from the group consisting of Si claim 3 , Ge claim 3 , and mixtures thereof.5. The process of claim 4 , wherein T is Si.6. The process of claim 3 , wherein X is selected from the group consisting of B claim 3 , Al claim 3 , Ga claim 3 , In claim 3 , and mixtures thereof.7. The process of claim 3 , wherein T is Si and X is Al.8. The process of claim 1 , wherein the process is a process selected from the group consisting of hydrocracking claim 1 , dewaxing claim 1 , catalytic cracking claim 1 , aromatics formation claim 1 , isomerization claim 1 , alkylation and transalkylation claim 1 , conversion of paraffins to aromatics claim 1 , isomerization of olefins claim 1 , xylene isomerization claim 1 , oligomerization claim 1 , condensation of alcohols claim 1 , methane upgrading and polymerization of 1-olefins.9. The process of claim 8 , wherein the process is a dewaxing process comprising contacting the catalyst with a hydrocarbon feedstock under dewaxing conditions.10. The process of claim 1 , wherein the process is a process for producing a C lube oil from a C olefin feed comprising isomerizing the olefin feed under isomerization conditions over the catalyst. The present disclosure relates to processes using a new molecular sieve designated SSZ-96, wherein the molecular sieve is synthesized using a 1-butyl-1-methyl-octahydroindolium cation as a structure directing agent (“SDA”).Because of their unique sieving characteristics, as well as their catalytic properties ...

REGENERATING SIEVE MATERIAL USED FOR PROCESSING NATURAL GAS

A system and process for regenerating sieve materials in a gas processing system. The process can include circulating a cooling gas through sieve material of a first bed, the cooling gas having a first concentration of carbon dioxide (CO2) suitable for liquefaction into a liquid natural gas (LNG) product. The process can also include circulating a regenerating gas through sieve material of a second bed, the regenerating gas having a second concentration of carbon dioxide (CO2) that is greater than the first concentration of carbon dioxide (CO2) of the cooling gas. 1. A process for regenerating sieve material in a gas processing system , said process comprising:circulating a cooling gas through sieve material of a first bed, the cooling gas having a first concentration of carbon dioxide (CO2) suitable for liquefaction into a liquid natural gas (LNG) product; andcirculating a regenerating gas through sieve material of a second bed, the regenerating gas having a second concentration of carbon dioxide (CO2) that is greater than the first concentration of carbon dioxide (CO2) of the cooling gas.2. The process of claim 1 , further comprising:purifying a feedstream to form a product gas in an outlet stream, the product gas having the first concentration of carbon dioxide (CO2); andforming the cooling gas from the product gas.3. The process of claim 2 , further comprising:mixing the cooling gas into the outlet stream downstream of the first bed.4. The process of claim 2 , further comprising:cooling the cooling gas downstream of the first bed.5. The process of claim 2 , further comprising:forming the regenerating gas in a main stream from the feedstream;heating the regenerating gas upstream of the second bed from a first temperature to a second temperature; andcontacting the regenerating gas with sieve material of the second bed at the second temperature.6. The process of claim 5 , further comprising:cooling the regenerating gas to the first temperature downstream of the ...

PROCESS FOR PRODUCING BIOMETHANE FROM A BIOGAS STREAM, COMPRISING SOLIDIFICATION OF THE IMPURITIES

Process for producing biomethane from a biogas stream including methane, carbon dioxide and at least one impurity chosen from ammonia, volatile organic compounds, water, sulfur-based impurities (HS) and siloxanes. A biogas stream is dried, the at least one impurity is at least partially removed by solidification and removal of the impurity. The methane and the carbon dioxide contained in the biogas obtained from the second step are separated so as to produce a biomethane stream and a COstream. 1. A process for producing biomethane from a biogas stream comprising methane , carbon dioxide and at least one impurity chosen from ammonia , volatile organic compounds , water , sulfur-based impurities (HS) and siloxanes , said process comprising the steps of:drying the biogas stream;at least partially removing said at least one impurity contained in the dried biogas stream by solidification and removal of the solidified at least one impurity to yield at least partially purified biogas; and{'sub': '2', 'separating the methane and the carbon dioxide contained in the at least partially purified biogas so as to produce a biomethane stream and a COstream.'}2. The process of claim 1 , wherein the second step of at least partially removing said at least one of the at least one impurity comprises:compressing the dried biogas stream to a pressure of greater than 5 bar, preferably 10 bar;cooling the compressed biogas stream to a temperature below −70° C., thereby solidifying said at least one impurity resulting in deposition of the solidified at least one impurity; andremoval of said solidified at least one impurity from the cooled compressed biogas stream.3. The process of claim 2 , wherein the compressed biogas stream is cooled with a cooling stream of COproduced during said step of separating.4. The process of claim 2 , wherein in said step of cooling claim 2 , said at least one impurity is removed by sublimation of said at least one impurity and by flushing with a gaseous ...

Natural Gas Liquids Recovery Process

Methods and systems for operating and NGL recovery process are provided. In an exemplary method, an absorber column upstream of a fractionator column is operated at a higher pressure than a pressure in the fractionator column. An NGL (Cplus) stream is taken from the bottom of a fractionator column and then ethylene/ethane stream is taken from the top of the fractionator column. A differential pressure between the absorber column and the fraction are column is controlled based, at least in part, on a flow rate of the fractionator feed stream from the absorber column to the fractionator column. 1. A control system for operating columns in a natural gas liquids (NGL) plant , comprising:a flow sensor to measure a flow rate of a fractionator column feed stream; an absorber column pressure sensor; and', 'an absorber column pressure control valve;, 'an absorber column pressure controller, comprising a fractionator column pressure sensor; and', 'a fractionator column pressure control valve; and, 'a fractionator column pressure controller, comprising [ the flow sensor;', 'the absorber column pressure sensor; and', 'the fractionator column pressure sensor;, 'a sensor interface to obtain measurements from, the absorber column pressure controller; and', 'the fractionator column pressure controller;, 'a controller interface to communicate set points to, 'a processor configured to execute stored instructions; and', [ the flow sensor;', 'the absorber column pressure sensor; and', 'the fractionator column pressure sensor;, 'read measurements from, 'calculate a set point for the absorber column pressure controller based, at least in part, on a set point for the flow rate; and', 'adjust the set point for the absorber column pressure controller to match the calculated value of the set point., 'a data store, comprising instructions configured to direct the processor to], 'a controller, comprising2. The control system of claim 1 , wherein the data store comprises instructions configured ...

WATER RECYCLING IN A CO2 REMOVAL PROCESS AND SYSTEM

Apparatuses, systems, and methods related to removing carbon dioxide from a gas stream are provided. Gas streams can be waste gas streams or natural gas streams. The systems and methods for removing carbon dioxide incorporate water repurposing schemes. Still others are disclosed. 1. A method of effectively reducing an amount of carbon dioxide from a gas stream comprising the steps of(a) generating an aqueous hydroxide solution in a chloro-alkali cell;(b) diluting the aqueous hydroxide solution to obtain a 5% to 15% by weight aqueous hydroxide solution;(c) admixing the diluted aqueous hydroxide solution with a first portion of a gas stream containing carbon dioxide to produce carbonate in a first admixture; and(d) removing water from the first admixture in a water removal unit;(e) after step (d), admixing the first admixture with a second portion of the gas stream to produce bicarbonate in a second admixture.2. The method of claim 1 , wherein 20% to 30% of water is removed from the first admixture in step (d).3. The method of claim 1 , wherein 23% to 26% of water is removed from the first admixture in step (d).4. The method of claim 1 , where the diluted aqueous hydroxide solution has a concentration of 8% to 10%.5. The method of claim 1 , further comprising the steps of separating a liquid phase from a solid phase of the second admixture and adding as a diluent at least a portion of the liquid phase to the aqueous hydroxide solution in step (b).6. The method of claim 1 , where the second admixture comprises a liquid phase and a solid phase and the method further comprises the steps of separating the liquid phase from the solid phase and returning at least a portion of the liquid phase to the second admixture where the first admixture is admixed.7. The method of claim 1 , where the second admixture comprises a liquid phase and a solid phase and the method further comprises the steps of separating the liquid phase from the solid phase and adding at least a portion of ...

Process For The Treatment Of Liquefied Hydrocarbon Gas Using 2-Amino-2-(Hydroxyethyl) Propane-1,3-Diol Compounds

A method for treating liquefied hydrocarbons comprising acid gases to remove said the 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 weight % to 90 weight % of said first amine compound and additionally comprises from about 1 weight % to 90 weight % of a second amine compound.3. The method of claim 1 , wherein said absorbent aqueous solution comprises from about 0.1 weight % to 50 weight % of said first amine compound and additionally comprises from about 5 weight % to 50 weight % of a second amine compound.4. The method of claim 1 , wherein Rand Rare hydrogen.5. The method of claim 1 , wherein Rand Rare methyl.6. The method of claim 1 , wherein Ris hydrogen and Ris methyl.7. 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.8. 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 , 1-hydroxyethylpiperazine claim 1 , 3-(piperazin-1-yl)propane-1 claim 1 ,2-diol claim 1 , 3 claim 1 ,3′-(piperazin-1 claim 1 ,4-diyl)bis(propane-1 claim 1 ,2-diol) and mixtures thereof.9. 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 , 342-(hydroxyethyl)methylamino)propane-1 claim 1 ,2-diol claim 1 , 3-(methylamino)bis(propane-1 claim 1 ,2-diol) claim 1 , amino-tris(propane-1 claim 1 ,2-diol) ...

ELECTROLYZED WATER-AMINE COMPOSITIONS AND METHODS OF USE

The invention is directed to a germicidal treatment fluid comprising electrolyzed water and an amine, and methods for producing and using same to kill microorganisms which produce hydrogen sulphide or sulphate-reducing bacteria. 1. A method of killing sulphate reducing microorganisms or microorganisms which can generate hydrogen sulphide , comprising the step of contacting the microorganism with a treatment fluid comprising a reaction product of electrolyzed water and an amine.2Desulfovibrio. The method of wherein the microorganism comprises species.3. The method of wherein microorganism is present in an environment contaminated by hydrogen sulphide.4. The method of wherein the microorganism is present in a wellbore or subterranean formation.5. The method of wherein the treatment fluid is injected into the wellbore or into the subterranean formation.6. The method of wherein the amine comprises an amino alcohol.7. The method of wherein the amino alcohol comprises monoethanolamine.8. A germicidal treatment fluid comprising a reaction product of electrolyzed water and an amine.9. The treatment fluid of produced by mixing electrolyzed water in an amount between about 20% to about 80% by volume and an amine in an amount between about 20% to about 80% by volume based on the total volume of the treatment fluid.10. The treatment fluid of produced by mixing electrolyzed water and an amino alcohol in about equal volumes.11. The treatment fluid of wherein the electrolyzed water comprises anolyte and catholyte.12. The treatment fluid of wherein the pH of the treatment fluid is above about pH 12.0.13. The treatment fluid of further comprising methanol or a dissolved salt.14. The treatment fluid of wherein the electrolyzed water comprises greater than about 4000 ppm of free available chlorine prior to mixing with the amine.15. The treatment fluid of which comprises substantially no free available chlorine.16. The treatment fluid of wherein the amine comprises an amino alcohol17. ...

Landfill Gas Treatment Method With Polishing and Post-Treatment Enrichment

A method for recovering methane gas from a landfill involves the use of a main absorber, a flash system, an optional ancillary absorber and an optional polishing absorber. The recovered gas is maintained at a temperature that enhances a solvent's ability to absorb carbon dioxide from the recovered gas. While the main absorber uses the solvent for absorbing most of the carbon dioxide from the recovered gas, the flash system removes much of the carbon dioxide from the solvent exiting the main absorber. In some examples, at least portion of the flash system operates at subatmospheric pressure to create a vacuum that draws in a generally inert stripper gas (e.g., air, nitrogen, etc.) at atmospheric pressure. The stripper gas helps remove carbon dioxide from the solvent in the flash system. 1. A method for using a solvent in treating a gas from a landfill , wherein the gas and the solvent have a varying concentration of carbon dioxide , the method comprising:conveying the gas through a main absorber;conveying substantially all of the gas from the main absorber through a polishing absorber;conveying at a main mass flow rate a main current of solvent through the main absorber, thereby exposing the gas to the main current of solvent;the main current of solvent extracting carbon dioxide from the gas;conveying at a polishing mass flow rate a polishing current of solvent through the polishing absorber, thereby exposing the gas to the polishing current of solvent;the polishing current of solvent extracting additional carbon dioxide from the gas, the main mass flow rate through the main absorber being at least three times greater than the polishing mass flow rate in the polishing absorber;the gas exiting the main absorber;the gas exiting the polishing absorber; andincreasing an energy content of the gas by adding propane to the gas after the gas exits both the main absorber and the polishing absorber, thus adding propane to the gas outside of both the main absorber and the ...

Composite Membranes

A process for preparing a composite membrane comprising the steps: a) applying a radiation-curable composition to a porous support; b) irradiating the composition present on the support, thereby forming a gutter layer of cured polymer; c) forming a discriminating layer on the gutter layer; and d) applying a radiation-curable composition to the discriminating layer and irradiating that composition, thereby forming a protective layer on the discriminating layer; wherein one or both of the radiation-curable compositions applied in steps a) and d) comprise a photo acid generator having an absorbency coefficient ε at 313 nm of more than 1×10mol*cm. Also claimed are composite membranes and gas separation cartridges comprising the membranes. 1. A process for preparing a composite membrane comprising the steps:a) applying a radiation-curable composition to a porous support;b) irradiating the composition present on the support, thereby forming a gutter layer of cured polymer;c) forming a discriminating layer on the gutter layer; andd) applying a radiation-curable composition to the discriminating layer and irradiating that composition, thereby forming a protective layer on the discriminating layer;{'sup': 4', '−1', '−1, 'wherein one or both of the radiation-curable compositions applied in steps a) and d) comprise a photo acid generator having an absorbency coefficient ε at 313 nm of more than 1×10mol*cm.'}2. The process according to wherein the radiation-curable composition applied in step a) comprises a photo acid generator having an absorbency coefficient ε at 313 nm of more than 1×10molcm.3. The process according to wherein the radiation-curable composition applied in step a) comprises a photo acid generator having an absorbency coefficient ε at 313 nm of more than 1×10mol*cmand the radiation-curable composition applied in step d) is free from photo acid generators having an absorbency coefficient ε at 313 nm of more than 1×10mol*cm.4. The process according to wherein the ...

Gas-To-Liquids Conversion Process Using Electron Beam Irradiation

A process for converting light alkanes from a natural gas production stream to higher molecular weight hydrocarbons is provided. The method includes transporting the natural gas stream to an electron beam reactor, such as a steel flow-type radiation reactor connected hermetically to an accelerator beam window. The gas stream is exposed to electron beam radiation to generate an upgraded and substantially liquefied hydrocarbon stream. The method then includes transporting the substantially liquefied hydrocarbon stream into a scrubber to remove non-condensed gases. The remaining liquid hydrocarbon stream is then transported as condensate to a distillation tower, where high octane products are separated through fractionation. 1. A process for converting a gas stream comprising primarily a mixture of light alkanes into a high-octane liquid stream , comprising:transporting the gas stream to a reactor at a gas processing facility;introducing the gas stream into a reactor whereupon components of the gas stream are exposed to electron beam radiation within the reactor to increase the molecular weight of hydrocarbons in the gas stream, thereby producing an upgraded radiolysis fluid stream;transporting the radiolysis fluid stream into a separator, thereby producing a first gaseous stream comprising primarily light alkanes, and a second liquid stream comprising primarily heavy alkanes;re-circulating the first stream back into an inlet of the reactor for additional irradiation and upgrading; andtransporting the liquid stream off-site for further processing or for commercial sale, wherein the liquid stream comprises a transportation fuel having an octane rating of at least 100.2. The process of claim 1 , further comprising:transporting the second liquid stream as condensate to a distillation column; andfractionating the condensate into separate products comprising at least heptane (and heptane isomers), hexane (and hexane isomers) and octane.3. The process of claim 1 , wherein ...

METHOD AND SYSTEM FOR PROVIDING UPGRADED BIOGAS

A method for providing upgraded biogas includes feeding a stream of biogas into a biogas upgrading system in order to remove carbon dioxide from the stream of biogas. The biogas upgrading system, which may be based on absorption, adsorption, membrane permeation, and/or cryogenics, provides a stream of upgraded biogas and a tail gas stream. The tail gas stream, which may be CO-rich, is enriched with natural gas so that it is combustible in medium-BTU equipment. The upgraded biogas is used for transportation use and/or the generation of fuel credits. Accordingly, both the tail gas and the upgraded biogas are used effectively and at lower cost. 1. A method of providing upgraded biogas comprising:feeding biogas into a biogas upgrading system, said biogas upgrading system producing upgraded biogas;enriching tail gas produced by the biogas upgrading system with natural gas to provide an enriched tail gas, said enriching comprising feeding natural gas withdrawn from a distribution system into at least one of the biogas upgrading system and the tail gas;providing at least a portion of the enriched tail gas to a combustion system, said combustion system configured to produce at least one of heat and electricity; andfeeding at least a portion of the upgraded biogas to the distribution system,wherein the amount of natural gas withdrawn from the distribution system for said enriching is at least 50% of the amount of upgraded biogas fed into the distribution system, each of said amount of natural gas and said amount of upgraded biogas measured as energy delivered over a period of time.2. The method according to claim 1 , wherein enriching the tail gas comprises mixing the natural gas withdrawn from the distribution system with the tail gas after the tail gas exits the upgrading system.3. The method according to claim 1 , wherein enriching the tail gas comprises feeding the natural gas withdrawn from the distribution system into the biogas upgrading system.4. The method according ...

METHOD AND SYSTEM FOR PRODUCING A CHEMICAL OR FUEL

A method for providing a fuel includes providing a partially purified biogas at a first processing site, where the partially purified biogas is produced by multiple biogas sources and/or from multiple feedstock sources. The partially purified biogas is compressed, fed to a mobile tank, and transported by vehicle to a second processing site. At the second processing site, which may also receive biogas from a plurality of biogas sources, the partially purified biogas is further processed to produce a fuel or fuel intermediate. 120-. (canceled)21. A method for producing a chemical or fuel comprising:(a) at a first processing site, receiving biogas from a first plurality of biogas sources, the biogas received from each biogas source being raw biogas or partially purified biogas;(b) at the first processing site, processing the biogas received in (a) and feeding the processed biogas into one or more mobile tanks until each mobile tank is pressurized to at least 1000 psig, the processing comprising partial purification, compression, or a combination thereof;(c) transporting the one or mobile tanks pressurized to at least 1000 psig to a second other processing site;(d) removing the processed biogas from the one or more mobile tanks transported in step (c); and(e) producing the chemical, fuel, or fuel intermediate using feedstock comprising methane from the processed biogas removed in step (d) and fossil-based methane.22. The method according to claim 21 , wherein said second processing site is configured to receive biogas from a second other plurality of biogas sources.23. The method according to claim 21 , wherein each biogas source in the first plurality of biogas sources is connected to the first processing site by pipeline.24. The method according to claim 22 , wherein each biogas source in the second plurality of biogas sources is connected to the second processing site or to a third other processing site by pipeline.25. The method according to claim 24 , wherein each ...

PROCESS AND PLANT FOR REMOVING THIOLS FROM SYNTHESIS GAS

The invention relates to a process and a plant for removing thiols from synthesis gas. Thiols and optionally thiophene and carbon disulfide are absorbed in a dedicated absorption stage with methanol as physical absorption medium. Methanol laden with at least thiols is freed of thiols in a stripping stage with methanol vapours as stripping gas and the methanol vapours-containing thiols are freed of methanol in a scrubbing stage. The process according to the invention minimizes methanol losses and the amounts of coolant required for the process. 1. A process for removing thiols from synthesis gas in a gas scrubbing process with methanol as physical absorption medium , comprising:(a) removing thiols from synthesis gas in an absorption stage configured for the removal of thiols by physical absorption of the thiols in methanol, wherein the absorption stage affords methanol laden with thiols and further co-absorbed gas components;(b) treating the laden methanol obtained according to step (a) in a stripping stage with methanol vapour as stripping gas to obtain a thiols- and methanol-comprising gaseous mixture and liquid methanol laden with co-absorbed gas components;(c) withdrawing the liquid methanol laden with co-absorbed gas components from the stripping stage according to step (b);(d) withdrawing the thiols- and methanol-comprising gaseous mixture from the stripping stage according to step (b);(e) removing methanol from the gaseous mixture withdrawn according to step (d) in a scrubbing stage by scrubbing with water to obtain a methanol- and water-comprising liquid mixture and gaseous thiols at least partially freed of methanol;(f) withdrawing the gaseous thiols at least partially freed of methanol from the scrubbing stage according to step (e); and(g) withdrawing the methanol- and water-comprising liquid mixture from the scrubbing stage according to step (e).2. The process according to claim 1 , wherein the gaseous mixture obtained according to step (b) is cooled to ...

Biogas plant and biogas treatment

A biogas plant includes a fermenter, a biogas processing unit and a thermal engine. The biogas processing unit includes a gas separation unit and a compression unit for the separation of raw biogas from the fermenter into two gas streams, whereby the first gas stream includes a product gas that is enriched in biomethane with respect to the composition of the raw biogas and the second gas stream includes a residual gas that is enriched with carbon dioxide with respect to the composition of the raw biogas and has a biomethane concentration of less than 20%. The thermal engine produces energy that is used for operation of the compression unit.

Configurations And Methods For Processing High Pressure Acid Gases With Zero Emissions

Plants, processes, and methods for reducing the HS and COcontents of shale gasses from fields that produce shale gasses having varying HS and COcontents are provided. Acid gas enters an absorber and is scrubbed using a lean physical solvent, producing a treated gas and a rich physical solvent. The HS content of the treated gas is further reduced in an amine absorber, producing a pipeline gas and a semi-lean amine. The pipeline gas contains lower levels of HS and COthan gas produced using a polishing bed. A physical solvent regeneration unit regenerates the lean physical solvent from the rich physical solvent for feeding into the absorption unit. An amine regeneration unit regenerates the lean amine from the semi-lean amine for feeding into the amine absorber. Contemplated plants may further comprise a Claus Unit or a Redox unit for oxidizing HS to elemental sulfur. 1. An acid gas processing plant , comprising:an absorption unit configured to (i) receive a feed gas comprising H2S and CO2 and (ii) use a lean physical solvent to absorb a portion of H2S and CO2 within the feed gas to produce a treated gas and a rich physical solvent;an amine absorber coupled to the absorption unit and configured to (i) receive the treated gas from the absorption unit and (ii) use a first portion of a lean amine to absorb a portion of H2S and CO2 within the treated gas to produce a pipeline gas and a semi-lean amine;a physical solvent regeneration unit coupled to the absorption unit and configured to (i) receive the rich physical solvent from the absorption unit and (ii) regenerate the lean physical solvent from the rich physical solvent for feeding into the absorption unit; andan amine regeneration unit coupled to the amine absorber and configured to (i) receive the semi-lean amine from the amine absorber and (ii) regenerate the lean amine from the semi-lean amine for feeding into the amine absorber.2. The plant of claim 1 , wherein the physical solvent regeneration unit comprises (i) a ...