A method of recovery of rich gas where the rich gas is a hydrocarbon gas comprising less than 50 mole % methane is disclosed. The method comprises the steps of gathering the low pressure gas, compressing the gathered gas, cooling the compressed gas in a condenser so that a portion of the compressed gas condenses to form a liquefied gas and liquefied gas vapour in the condenser, and discharging the liquefied gas and liquefied gas vapour from the condenser, in which the cooling of the compressed gas is performed using at least one heat exchanger (40).

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.

The present disclosure provides methods for identifying a hydrocarbon fuel, such as the presence and/or amounts of marker compounds having a fluorescence intensity and, through correlation, the presence and/or amounts of additive package(s) within the hydrocarbon fuel.

Production chemicals and methods of selecting the production chemicals based on Hansen Solubility Parameters (HSP) are disclosed. The production chemicals selected by the methods mitigate or reduce one or more issues or problems associated with oil and gas productions and transportations. The methods measure HSP values for the production chemicals and/or crude oil and select at least one production chemical for at least one application on the crude oil based on the HSP values of the production chemicals and the crude oil.

Various illustrative embodiments of a system and process for recovering high-quality biomethane and carbon dioxide product streams from biogas sources and utilizing or sequestering the product streams are provided. The system and process synergistically yield a biomethane product which meets gas pipeline quality specifications and a carbon dioxide product of a quality and form that allows for its transport and sequestration or utilization and reduction in greenhouse gas emissions. The system and process result in improved access to gas pipelines for products, an improvement in the carbon intensity rating of the methane fuel, and improvements in generation of credits related to reductions in emissions of greenhouse gases.

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 pressure measurement device, 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 temperature of the first retentate is adjusted at an inlet of the second membrane separation unit with at least one heat exchanger as a function of the measured CH.sub.4 concentration in such a way so as to reduce the determined difference.

An energy conversion system includes a fuel synthesis device, an H.sub.2O supply unit, a CO.sub.2 supply unit, and a supply control unit. The fuel synthesis device includes an electrolyte, and a pair of electrodes provided on both sides of the electrolyte. The H.sub.2O supply unit supplies H.sub.2O to the fuel synthesis device. The CO.sub.2 supply unit supplies CO.sub.2 to the fuel synthesis device. The supply control unit controls a supply of H.sub.2O and a supply of CO.sub.2. The fuel synthesis device electrolyzes H.sub.2O and CO.sub.2 using external electric power, and synthesizes a hydrocarbon using H.sub.2 and CO generated by electrolysis. The supply control unit starts the supply of H.sub.2O to the fuel synthesis device by the H.sub.2O supply unit after the supply of CO.sub.2 to the fuel synthesis device by the CO.sub.2 supply unit is started.

This invention provides processes and systems for converting biomass into high carbon biogenic reagents that are suitable for a variety of commercial applications. Some embodiments employ pyrolysis in the presence of an inert gas 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.

A method of characterizing chemical and/or morphological features of a material, comprising acquiring energy relaxation data from 1H low field nuclear magnetic resonance (.sup.1H LF-NMR) measurements of said material, converting the relaxation signals into a multidimensional distribution of longitudinal and transverse relaxation times by solving an inverse problem under both L.sub.1 and L.sub.2 regularizations and further imposing a non-negativity constraint, and identifying one or more characteristics of said material with the aid of said multidimensional T1-T2 distribution. The method is useful, inter alia, in monitoring chemical processes, screening of additives and quality control.

Naphtha boiling range compositions are provided that are formed from crude oils with unexpected combinations of high naphthenes to aromatics weight and/or volume ratio and a low sulfur content. The resulting naphtha boiling range fractions can have a high naphthenes to aromatics weight ratio, a low but substantial content of aromatics, and a low sulfur content. In some aspects, the fractions can be used as fuels and/or fuel blending products after fractionation with minimal further refinery processing. In other aspects, the amount of additional refinery processing, such as hydrotreatment, catalytic reforming and/or isomerization, can be reduced or minimized. By reducing, minimizing, or avoiding the amount of hydroprocessing needed to meet fuel and/or fuel blending product specifications, the fractions derived from the high naphthenes to aromatics ratio and low sulfur crudes can provide fuels and/or fuel blending products having a reduced or minimized carbon intensity.