Streamline Innovations Gmbh

Franklin Hailey Brown, Ii

Peter J Photos

David Sisk

John C Bourdon

Billy G Clark

Benjamin Isaac Tyler

Michael A Pue

Trey Taylor

A multi-directional contactor apparatus configured to utilize co-current and counter current flow to contact a first fluid and a second fluid, wherein the second fluid is more dense than the first fluid. The contactor comprises a chamber partially divided by a vertically extending weir, a first inlet port permitting the first fluid to enter the chamber, a second inlet port positioned above the first inlet port and permitting the second fluid to enter the chamber. Countercurrent and co-current contact of the first and second liquids occurs on one side of the weir. The weir separates the co-current contacted second fluid stream from the countercurrent contacted second fluid stream and allows the separated streams to be released from the chamber. The co-current and countercurrent contacted first fluid is released from an upper portion of the tank.

Co-current and countercurrent contactor for immiscible fluids

A surfactant composition in aqueous phase includes 0.5% to 15% by weight of an alkoxylated block copolymer and 0.5% to 15% by weight of an alcohol ethoxylate. The non-ionic alkyl ethoxylate is a fast wetting agent. The block copolymer, which is characterized by a longer wetting time than the non-ionic alkyl ethoxylate, disrupts the emulsion and allows the now-coated sulfur particles to escape the existing emulsion. The composition may also include an alkyl alcohol and/or glycol ether. The alkyl alcohol augments the emulsion-breaking capabilities of the diblock copolymer by providing additional surface tension reduction to the system, as well as emulsion inhibition at the aqueous-gaseous interface. The glycol ether acts as a mutual solvent, which also augments the emulsion breaking capabilities of the diblock copolymer by providing additional surface tension reduction to the system, as well as emulsion inhibition at the aqueous-gaseous interface.

Reducing slurry emulsion and foaming in oxidation-reduction sulfur removal processes

An integrated amine and redox gas treatment system is configured to treat an influent hydrocarbon containing stream. The system includes a reduction oxidation unit connected directly downstream of an amine unit. The amine unit is configured to separate the influent fluid stream into a first amine effluent stream including hydrocarbons and a second amine effluent stream including a connection pressure and comprising CO. The reduction oxidation unit is configured to receive the second amine effluent stream from the amine unit and operate at the connection pressure while releasing a reduction oxidation effluent stream including purified CO. The connection pressure includes a single pressure or a plurality of pressures at which both the amine unit and the reduction oxidation unit are configured to operate.

Gas purification apparatus and method

A dynamically adjustable rate sulfur recovery process continuously calculates and adjusts sour gas stream operating pressure and/or flow rate to maximize sweet gas output, thereby improving efficiency. A corresponding desulfurization system may include a fixed-sized pressure vessel, a flow control valve that controls the rate of flow of a sour gas stream into the pressure vessel, a sensor that measures sulfur concentration in the sour gas stream, a reagent tank, an oxidizer tank, and a phase separator that separates sweet gas as a gaseous phase after hydrogen sulfide in the sour gas stream in the pressure vessel is converted to elemental sulfur, sulfur species, or both by contact with reagent from the reagent tank and oxidizer from the oxidizer tank. A PLC (programmable logic controller) continuously calculates updated flow rates based on sulfur concentration measurements from the sensor to achieve maximum sweet gas production.

Field processing natural gas for sulfur recovery with dynamically adjustable flow rate control

An oxidation-reduction desulfurization system includes a reactor vessel with sour gas inlet at the bottom and a gas outlet at the top. A primary stage phase separator includes a vertically-oriented pipe with an inlet located inside the reactor vessel. The ratio of the reactor vessel diameter to the pipe inlet diameter is in a range of 2:1 to 5:1. Surface foam and non-gaseous multi-phase mixture including emulsion flow into a partially gas-filled upper section of the vertically-oriented pipe and freefall to a lower level, thereby facilitating mechanical breaking of the foam and the emulsion. A secondary stage phase separator connected to the gas outlet separates non-gaseous surge from sweet gas. Valves and a controller automatically maintain target levels of the non-gaseous multi-phase mixture and non-gaseous surge.

Separating sweet gas from a sour gas stream

A small-scale system for removing hydrogen sulfide and ammonia from a wastewater stream includes a sulfur recovery stage, an ammonia recovery stage, and a separation stage. Sulfur species are oxidized and converted into solid sulfur and solid sulfur species by exposure to a combination of chelated iron and oxidizer. The solid sulfur and solid sulfur species are removed by filtration to yield a sulfur-free stream to which oxidizer is added and electromagnetic radiation is inputted to break the N&#x2014;H bonds of the ammonia into amine radicals. The combination of additional oxidizer and electromagnetic radiation promotes the creation of water and nitrogen gas.

Growing community of inventors

San Antonio, TX, United States of America

Franklin Hailey Brown, Ii