The Dow Chemical Company

Dow Global Technolgoies LLC

Alstom Technology Limited

General Electric Technology Gmbh

Other

Stephen A Bedell

Larry H Kirby

William Monroe Coleman, Iii

Dane Chang

Frederic Vitse

William R Howell, Jr

Susan S Kuan Tsai

Felipe A Donate

Sanjay Kumar Dube

Peter C Rooney

Barath Baburao

Jonathan W Leister

Peter Ulrich Koss

Ross E Dugas

Richard D Varjian

Nareshkumar B Handagama

Aubrey J Rhymes, Jr

John D Myers

Charles A Hammond

Susan S Tsai

Joseph R Downey

John M Griffin

Clare M Worley

Johnathan W Leister

A system for the removal of heat stable amine salts from an amine absorbent used in a carbon dioxide (CO) capture process.

System for the removal of heat stable amine salts from an amine absorbent

A system for recovering ammonia from a gas stream is provided. The system includes a regenerator and a carbon dioxide wash station.

System and method for recovering ammonia from a gas stream

Systems and process for volatile degradation removal from amine plant wash water are provided. The systems and processes include a separation device disposed within a water circulation loop and configured to continuously remove at least a portion of the volatile degradation products from the wash solutions. The separation device can be configured for stripping, distillation, and/or extraction of the volatile degradation products from at least a fraction of the spent wash water. Optionally, a chemical agent can be reacted with the volatile degradation products to form heat stable salts for subsequent removal.

Systems and processes for removing volatile degradation products produced in gas purification

A carbon dioxide capture system includes a solid sorbent material including an amine. A base solution is in communication with the sorbent material when the amine becomes deactivated. The base solution is removed from the sorbent material when the amine is regenerated by the base solution.

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A system and method for removing carbon dioxide from a gas stream. One aspect of the method includes introducing a carbon dioxide containing gas stream to an absorber; contacting the gas stream with an amine-containing solvent; absorbing, with the amine-containing solvent, the carbon dioxide from the gas stream, thereby removing the carbon dioxide from the gas stream; and forming a precipitate with the amine-containing solvent and the carbon dioxide.

Method and system for low energy carbon dioxide removal

A structural low carbon steel in combination with and in contact with an aqueous MDEA solvent that includes as an amine-based chemical additive. When mixed with MDEA solvent to form a MDEA solution, the MDEA-based solution in contact with carbon steel reduces the corrosion rate of low carbon structural carbon steels having a carbon content greater than about 0.18% by weight is significantly reduced when the concentrations of CO, Oand heat stable salts (HSS) are controlled below critical amounts. The MDEA solution, when controlling the concentrations of CO, Oand HSS below critical amounts, suppresses the corrosion of carbon steel having a carbon content greater than about 0.18%. A smooth surface finish further suppresses the corrosion of the low carbon structural steel. When the CO, Oand HSS are maintained below critical values, a low carbon structural steel having a micropolished surface finish displayed improved corrosion resistance.

Reduced carbon steel corrosion in CO2-O2 amine environment

The present invention relates to making tetra-sulfo iron-phthalocyanine by reacting sulfonated reactant(s) in the presence a boron-containing promoter. The present invention also relates to making tetra-sulfo iron phthalocyanine more tolerant to oxygen by combining the tetra-sulfo iron-phthalocyanine with a stabilizing amount of a complexing agent (e.g., a stabilizing amine) and/or contacting the tetra-sulfo iron-phthalocyanine with steam.

Tetra-sulfo iron-phthalocyanine and related methods

A composition for removing mercaptan from a gas stream containing at least one acid gas in addition to a mercaptan, the composition comprising a physical and/or chemical solvent for HS and an inclusion compound for the mercaptan. A process of treating gas stream using the composition. The inclusion compound is selected from the group consisting of, cyclodextrin, cryptand, calixarene, cucurbituril. The chemical solvent may be monoethanolamine (MEA), diethanolamine (DEA), triethanolamine (TEA, diisopropylamine (DIPA), diglycolamine (DGA) and methyldiethanolamine (MDEA). Examples of useful physical solvents include cyclotetramethylene sulfone (sulfolane) and its derivatives, aliphatic acid amides, NMP (n-methylpyrrolidone), N-alkylated pyrrolidones and corresponding piperidone, methanol and mixtures of dialkethers of polyethylene glycols. The method comprises scrubbing preferably the natural gas with an aqueous solution comprising the above compounds followed by a stripping regeneration step.

Method and composition for removal of mercaptans from gas streams

A process is disclosed for removing aromatics, and volatile organic hydrocarbons from a gaseous fluid stream including passing the fluid stream in contact with a dehydrating composition comprising a glycol selected from triethylene glycol, ethylene glycol, diethylene glycol, or mixtures thereof and a hydrocarbon solubility depressant. The dehydrating composition may also contain a dissolved salt including at least one alkali metal carboxylate, an ammonium carboxylate, an alkali metal halide, an ammonium halide, or a mixtures thereof.

Gas drying process using glycol solution solubility suppressants

The simultaneous abatement of NO and SO.sub.2 in flue gas is provided by an absorption process and apparatus utilizing an absorbent composition comprising an aqueous solution of chelates and sulfite salt for NO abatement and amine SO.sub.2 absorbents such as piperazinones, morpholinones, piperidines, piperazines, piperazinediones, hydantoins, triazinones, pyrimidinones, oxazolidones, etc. for SO.sub.2 abatement. SO.sub.2 is thermally stripped from the spent absorbent and recovered. Metal chelates oxidized to an inactive state as a side-reaction are electrochemically reduced. An anionic exchange membrane in the electrochemical cell regenerates heat stable amine salt byproducts to be converted back to useable amine sorbent, and facilitates removal from the absorbent solution of other waste salts.

Method for simultaneous absorption of sulfur dioxide and nitric oxide

H.sub.2 S is removed from a fluid stream by contacting the stream with an aqueous solution having at least two components: an effective amount of an iron (III) chelate to oxidize H.sub.2 S to sulfur and, an amount of a water soluble anionic polymer containing sulfonic acid groups, carboxyl groups or mixtures thereof which is effective to stabilize the chelate. During the removal process the iron chelate is reduced to iron(II) chelate, and sulfur particles are produced.

Removal of hydrogen sulfide from fluid streams

The simultaneous abatement of NO and SO.sub.2 in flue gas is provided by an absorption process and apparatus utilizing an absorbent composition comprising an aqueous solution of chelates and sulfite salts. Metal chelates oxidized to an inactive state are electrochemically reduced. In the electrochemical cell, nickel or stainless steel anode materials are stable and may be used in the place of platinum coated anode materials when the anolyte pH is maintained greater than 12. At these conditions, the anode is corrosion resistant with a long operating time between replacement. Ultrafiltration or Donnan dialysis may be used to separate the chelate sorbents from the waste salts to reduce the loss of expensive chelate sorbents. Alternatively, an anionic exchange membrane can be used to electrodialytically separate waste sulfur/nitrogen salts from the absorbent solution.

Process for absorption of sulfur dioxide and nitric oxide from flue gas

Inhibitors of oxidation of sulfites to sulfates in sulfur dioxide scrubbing solutions are disclosed. The inhibitors are cationic polyelectrolytes which are water soluble, have a molecular weight of at least 10,000 daltons and contain quaternary amine groups. The polyelectrolytes are preferably present at 1-3000 ppm in alkali solutions with which a sulfur dioxide containing gas stream is contacted. The scrubbing solutions contain amines such as piperazinones, morpholinones, piperidines, piperazines, piperazinediones, hydantoins, triazinones, pyrimidinones, oxazolidones, N-carboxymethyl ethylenediamines, etc.

Quaternary polyamines as sulfite oxidation inhibitors in amine scrubbing

H.sub.2 S abatement in geothermal drilling operations (e.g. drilling, flow testing and reworking) with a ferric aminocarboxylic acid chelating solution containing a stabilizer and an optional cationic polyelectrolyte catalyst which is injected in the blooie line of the well upstream of the separator. The stabilizer is a hydroxyl radical scavenger such as iodide, nitrite, amino acid, aliphatic aldehyde, sugar, ascorbate, formate and/or aryl sulfonic acid, and inhibits degradation the ferric aminocarboxylic acid complex.

H.sub.2 S abatement with stabilized chelates in geothermal drilling

In a process of cyclodimerizing a conjugated diene to form a cycloalkene using a soluble iron complex as catalyst, the improvement comprises using as an inhibitor of diene polymerization, at least one hindered phenol.

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Lake Jackson, TX, United States of America

Stephen A Bedell