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.

Process for retrofitting existing processing units for natural gas fee streams. A portion of the dehydration adsorbent is removed from the vessels of the dehydration unit and is replaced with an adsorbent for heavy hydrocarbons. In operation the vessels are operated in thermal swing adsorption processes with reduced cycle times compared to the original design.

A system for forming a woody biomass component and a binder component into a solid fuel element having a predetermined density. The system includes a first compression assembly for compressing an uncompressed mixture of the woody biomass component and the binder component to provide a first compressed mixture formed into a preliminary element having a preliminary density. The system also includes a second compression assembly for compressing the preliminary element to form the solid fuel element having the predetermined density, which is greater than the preliminary density.

A system includes a first separator that separates water from a fluid material. The water settles on the bottom of the water knock-out tank. The system includes multiple compressors to boost the pressure of the fluid material. The system includes a second separator that separates condensate from the fluid material. The system includes a mixing pipe that mixes glycol with the fluid material and a first heat exchanger that cools the mixed fluid material and glycol. The system includes a third separator that separates gaseous components and liquid components of the mixed fluid material and glycol and a fourth separator that separates the liquid components of the mixed fluid material and glycol. The system includes a fractional distillation column that heats a first liquid from the fourth separator, gasifying a first portion of the first liquid. A second portion of the first liquid remains liquid and is natural gas liquids.

A method, system, and apparatus for managing variable, multi-phase fluid conversion to output fuel and energy for providing customizable management for processing a volume of natural gas including a volume of methane and a volume of other alkanes that may be cleaned of the other alkanes using a conversion system to create synthesis gas and other fuel products to be used in onsite or combined heat and power or cogeneration applications. In particular, the method, system, and apparatus provide for automated feedback and control directing various gas constituents to different application units with allocations according to settings system parameters to quickly and efficiently meet the demand for various products while making adjustments in real-time.

Processes, systems, and associated control methodologies are disclosed that control the flow of biogas during the biogas cleanup process to create a more consistent flow of biogas through the digester, while also optimizing the output and efficiency of the overall renewable natural gas facility. In representative embodiments, a biogas buffer storage system may be used during the cleanup process to control the pressure and flow rate of biogas. The biogas buffer storage system may monitor and control the biogas flow rate to either bring down or increase the digester pressure, thereby maintaining a normalized biogas flow rate.

A marking method which is a method of marking a product having a distillation range is disclosed. The method comprises the step of adding to said product a first marker, a second marker and optionally one or more further markers. Each marker has a distillation range including a minimum boiling point (Min BP), a maximum boiling point (Max BP) and a maximum distillation boiling point (Max DBP) which is the temperature at which the maximum volume of the marker distils. Each marker has a different distillation range from each other marker and at least one marker has a Max DBP which is within the distillation range of the product. The first marker has a distillation range in the marked product which extends over the whole of the product distillation range.

A Liquid, comprising an hydrophobic flavonoid derivative electrochemically non-active, that is capable of restoring its electrochemical activity, the concentration of the flavonoid derivative being 10 ppm by weight or less, and an organic substance in an amount of 90% by weight or more.

Processes and systems for converting biomass into high-carbon biogenic reagents that are suitable for a variety of commercial applications. Pyrolysis in the presence of an inert gas is employed to generate hot pyrolyzed solids, condensable vapors, and non-condensable gases, followed by separation of vapors and gases, and cooling of the hot pyrolyzed solids in the presence of the inert gas. Additives may be introduced during processing or combined with the reagent, or both. The biogenic reagent may include at least 70 wt %, 80 wt %, 90 wt %, 95 wt %, or more total carbon on a dry basis. The biogenic reagent may have an energy content of at least 12,000 Btu/lb, 13,000 Btu/lb, 14,000 Btu/lb, or 14,500 Btu/lb on a dry basis. The biogenic reagent may be formed into fine powders, or structural objects. The structural objects may have a structure and/or strength that derive from the feedstock, heat rate, and additives.

Automated methods and systems for blending high sulfur hydrocarbons, particularly those derived from transmix, into low sulfur hydrocarbon streams are provided. Also provided are methods for splitting transmix into usable hydrocarbon fractions and blending the fractions back into defined hydrocarbon streams.