An aromatic pre-blend for use in preparing E10 test fuel in accordance with 40 CFR 1065.710(b) includes a mixture of aromatic compounds having C6-C10+ aromatic proportions as recited in 40 CFR 1065.710(b).

A fuel composition for use in internal-combustion engines has a fuel component, an alcohol component, a water component, a microemulsion blend, and a cetane-enhancer component. The microemulsion blend includes at least one of lower grade fatty acid derivatives being present in an amount effective for the fuel, alcohol, and water components to form a microemulsion blend. The emulsifier is present in an amount effective for the biodiesel fuel, alcohol, water, and emulsifier to form an emulsion.

An intelligent controls system for a field-deployable system for producing dry natural gas (NG) and natural gas liquids (NGLs) from a raw gas stream is disclosed. The control system is used to ensure correct specifications of both dry NG (above a desired minimum methane number) and NGLs (below a desired maximum vapor pressure) from any supplied raw natural gas source by controlling three system parameters: inlet gas flow rate, system operating pressure, and separator-reboiler temperature set point. The input parameters include: heat content of the input gas stream, volume of the input gas stream, desired methane number of the NG, and desired vapor pressure of the NGLs. The controls system allows any piece of remote field equipment for performing complex chemical processing to be monitored, controlled, and operated remotely. A large array of distributed field equipment situated around the world can all be controlled primarily through a single interface provided in a central control center.

Disclosed are methods, systems, and computer-readable mediums for determining the composition of gaseous fuel. An initial gaseous fuel stream is provided that includes methane, non-methane hydrocarbons, and inert gases. Air is mixed into the initial fuel stream upstream of a first catalyst. The first catalyst oxidizes only the non-methane hydrocarbons of the initial fuel stream to produce a resultant fuel stream comprising methane and inert gases. Air is mixed into the resultant fuel stream downstream of the first catalyst and upstream of a second catalyst. The second catalyst oxidizes only the methane hydrocarbons of the resultant fuel stream to produce an output fuel stream. Mole ratios of the methane, the non-methane hydrocarbons, and the inert gases of the initial fuel stream are each determined.

A method of producing a fuel additive includes passing a feed stream comprising C4 hydrocarbons through a butadiene extraction unit producing a first process stream; passing the first process stream through a methyl tertiary butyl ether unit producing a second process stream and a methyl tertiary butyl ether product; passing the second process stream through a hydration unit producing the fuel additive and a recycle stream; passing the recycle stream through a hydrogenation unit; and recycling the recycle stream to a steam cracker unit and/or to the feed stream

The present disclosure provides an experimental loop system for fluidization exploitation of solid-state marine gas hydrate, comprising: four modules, namely a gas hydrate sample large-amount and rapid preparation module, a gas hydrate multi-scale smashing and slurry fidelity transfer module, a gas hydrate slurry pipeline conveying characteristic experiment module, and a data collection and monitoring and safety control module. The gas hydrate experimental loop device provided by the present disclosure may be used for researching the synthesis, decomposition, gas storage rate and phase equilibrium of gas hydrate, and researching the pipeline conveying flow resistance and heat transfer characteristics, and is significant for solving the blockage problem in the gas pipeline conveying process, storage and conveying of the gas hydrate, solid-state fluidization exploitation of the marine gas hydrate and pipeline conveying experimental simulation thereof.

The invention relates to a hydrocarbon blend for input to a refinery and comprising a first blend component containing a renewable hydrocarbon component and a second blend component containing petroleum derived hydrocarbon to form at least part of a final hydrocarbon blend for processing in a refinery where the first blend component is characterized by comprising a hydrocarbon substance with at least 70% by weight having a boiling point above 220° C. and by having the characteristics (δ.sub.d1, δ.sub.ρ1, δ.sub.h1)=(17-20, 6-12, 6-12) and; where the second blend component is characterised by having the characteristics (δ.sub.{acute over (α)}2, δ.sub.ρ2, δ.sub.h2)=(17-20, 3-5, 4-7), where the first blend component is present in the final hydrocarbon blend in a relative amount of up to 80 wt %.

A system including biogas purification and provides biogas as feedstock to a solid oxide fuel cell. The biogas purification treatment process provides a polished biogas that is substantially free of carbonyl sulfides and hydrogen sulfide. The system uses a biogas treatment apparatus, that includes apparatus such as a packed columns, comprising copper oxide or potassium permanganate packing material, and an activated carbon component configured to treat the biogas by polishing it to remove carbonyl sulfides and deleterious trace residues, such as hydrogen sulfide, that were not removed by any prior bulk H2S removal steps. In addition, an oil removal device is used to remove any entrained fine oil droplets in the biogas. A polished biogas having in the range of 60% methane is charged to the fuel cell. Electricity generated may be fed into a grid or used directly as energy to charge electrical-powered vehicles, for example. Energy credits are tracked in real time and are appropriately assigned.

The present disclosure provides a system and method for odorizing natural gas flowing through a distribution pipeline. The system includes a bypass line adjacent to a distribution pipeline, wherein bypass gas flows through the bypass line and an odorant tank connected to the bypass line, and into the distribution pipeline; a high-flow control valve and a low-flow control valve in the bypass line, wherein bypass gas flows through the odorant tank into the distribution pipeline when the high-flow control valve or the low-flow control valve is open; and a programmable logic controller connected to the high-flow and low flow control valve; wherein the programmable logic controller opens the high-flow or low-flow control valve for a predetermined dwell time proportional to an amount of bypass gas needed to odorize gas in the distribution pipeline each time that a preselected quantity of gas flows through the distribution pipeline.

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 gas analyser, at least one valve, and first, second, third, and fourth membrane separation units for separation of CO.sub.2 from CH.sub.4 to permeates enriched in CO.sub.2 and retentates enriched in CH.sub.4, respectively. A pressure of the feed gas flow is adjusted according to a CH.sub.4 concentration of the second retentate.