A reversing flow apparatus comprising a chamber having a series of two or more sequential rings mounted on a shaft extending axially through the chamber, the rings being separated by a space, each ring comprising a circumference and one or more S-shaped members extending from a point in the circumference to another point in the circumference and across a center of the ring, the two or more sequential rings being mounted along the shaft in a twist arrangement such that at least one ring In the apparatus has its S-shaped member in a forward-facing position and at least one ring in the apparatus has its S-shaped member in a reverse-facing position.

A reversing flow apparatus comprising a chamber having a series of two or more sequential rings mounted on a shaft extending axially through the chamber, the rings being separated by a space, each ring comprising a circumference and one or more S-shaped members extending from a point in the circumference to another point in the circumference and across a center of the ring, the two or more sequential rings being mounted along the shaft in a twist arrangement such that at least one ring In the apparatus has its S-shaped member in a forward-facing position and at least one ring in the apparatus has its S-shaped member in a reverse-facing position.

A demulsifier includes the reaction product of a) a combination of a monoglyceride and polyethylene glycol (PEG), b) an acid having at least two carboxyl groups, a full or partial ester thereof, an anhydride thereof and combinations thereof, and c) optionally, a fatty acid, a fatty alcohol and combinations thereof. A method of demulsifying a water-in-oil or oil-in-water emulsion includes adding the demulsifier to the emulsion and separating the emulsion into an oil phase and a water phase.

A system for recovering gel-mass from a gel-mass-containing waste material. The system includes mangle rolls, a heated accumulator for receiving and melting the gel-mass-containing waste material to provide an oil phase and a non-oil phase; a pumping system; an optional mixer; and a control system.

Various embodiments disclosed relate to surfactant compositions for treatment of subterranean formations and produced oil. In various embodiments, the present invention provides a method of treating a subterranean formation including placing in the subterranean formation a surfactant composition. The surfactant composition includes an alkanolamide surfactant and an alkoxylated alcohol surfactant. The surfactant composition also includes an ionic surfactant, a nonionic surfactant, or a combination thereof.

A method of treating contaminated materials such as oil and gas production waste sludges to recover crude oil hydrocarbons. The method includes the inversion of water-in-oil emulsions, and subsequent separation steps. These may involve the separation and removal of asphaltenes, petroleum waxes and/or solid particles from the crude oil hydrocarbons. The treatment method uses the physical phenomena of hydrodynamic cavitation and hydraulic shock, which produce different effects upon a mixture of water and the contaminated material being treated. These are deployed either as single or combined stage(s) of treatment or as a repeated series of single/combined treatment stages, with or without additional processing operations between each single/combined treatment stage. The method may be implemented with suitable plant including hydrodynamic cavitation units (103, 106) and hydraulic shock units (104, 107), followed by separators (105, 108).

A method for selecting a demulsifier and its concentration that is most efficient in separating water from oil includes mixing dry oil with a demulsifier to obtain a mixture having a first concentration; generating water droplets inside the mixture; pumping the water droplets and the mixture into a micro-fluidic channel; sending a laser beam through the micro-fluidic channel; recording images of the water droplets in the mixture with a camera; and calculating a percentage of the water droplets that coalescence inside the micro-fluidic channel when free-falling through the mixture, due to gravity.

A method of controlling a demulsifier dosage to an AC/DC modulated coalescer is described. The method includes monitoring a characteristic of an electric current drawn by an electrical component of the AC/DC modulated coalescer, determining if the characteristic of the electric current lies outside a predetermined stable range, and increasing the demulsifier dosage if the characteristic of the electric current lies outside the predetermined stable range. A system for controlling a demulsifier dosage to an AC/DC modulated coalescer with an adjustable dosing mixing valve is also described. The system includes a current sensor arranged to monitor an electric current drawn by an electrical component of the AC/DC modulated coalescer, and a processor configured to determine if a characteristic of the electric current lies outside a predetermined stable range. Furthermore, the system is configured to increase the demulsifier dosage if the characteristic of the electric current lies outside the predetermined stable range.

A method of processing thin stillage in an ethanol refining operation is provided. The method comprises treating thin stillage upstream of a concentration or evaporation step with an aid comprising a sorbitan ester of a fatty acid, an ethoxylated sorbitan ester of a fatty acid, or a combination thereof, thereby forming treated thin stillage. The aid may include at least one of sorbitan monooleate, polyoxyethylene sorbitan monostearate, and polyoxyethylene sorbitan monolaurate.

A natural gas processing system is mounted on a mobile platform that is transported to a natural gas source, such as a well. The system supplies retentate gas to operate multi-fuel engines for wellfield equipment such as pumps, compressors, and drills. A liquid drain discharges contaminants. A separator, first and second coalescing filters, and a particulate filter remove particulate matter and fluid contaminant matter from the natural gas. A dryer removes water vapor from the natural gas. Dual membranes separate the natural gas into a retentate gas and a permeate gas. A first heat exchanger adjusts temperature of the natural gas entering the membranes. A second heat exchanger adjusts temperature of the retentate gas output. A thermoelectric generator powered by the natural gas supplies process electricity. A process control monitors and controls the natural gas processing system, including pressure control valves, temperature control valves, and emergency shutdown systems. An instrument gas supply with an accumulator supplies gas pressure to operate pneumatic valves and instruments.