Abstract: A curable composition, a cured layer manufactured utilizing the same, and a display device including the cured layer are provided. The curable composition includes (A) a quantum dot; and (B) a polymerizable compound, wherein the polymerizable compound is a compound represented by Chemical Formula 1. In Chemical Formula 1, each substituent is the same as defined in the specification.

Abstract: A color conversion film material, a color conversion film, and a display device are provided. The material of the color conversion film includes a first compound and a second compound, and a mass ratio of the first compound and the second compound is (0.4-1.6):(0.3-1.7). A heat stability of the color conversion film is enhanced by using the color conversion film made of the material of the color conversion film. Moreover, a color gamut of the display device is improved, and costs thereof are reduced by applying the color conversion film to the display device.

Abstract: A quantum dot composition includes a quantum dot, and a ligand bonded to a surface of the quantum dot, wherein the ligand includes a head portion bonded to the surface of the quantum dot and containing a polar solvent dissociative functional group, and a tail portion connected to the head portion. A quantum dot composition according to an embodiment is used to form an emission layer of a light emitting element to enhance luminous efficiency of the light emitting element including an emission layer formed through the quantum dot composition.

Abstract: Disclosed are a quantum dot material, a method for patterning a quantum dot film and a quantum dot light emitting device. when preparing a patterned quantum dot film, firstly, a quantum dot film is made by using the quantum dot material with the photolysis group, and a corresponding region of the quantum dot film is irradiated with ultraviolet light under the shielding of a mask template, so that the photolysis group in the corresponding region is photolyzed into the polarity change group, thereby changing the solubility of the quantum dot material in the corresponding region; and subsequently, the quantum dot film is cleaned by using a solvent which can dissolve the quantum dot material with the photolysis group, the quantum dot material in non-irradiated regions is dissolved and removed, and the quantum dot material in the corresponding region is retained to form a pattern of the quantum dot film.

Abstract: A semiconductor nanocrystal can be made by an in situ redox reaction between an M donor and an E donor.

Abstract: A quantum dot including a core including a first semiconductor nanocrystal including a Group III-V compound; and a semiconductor nanocrystal shell disposed on the core, the semiconductor nanocrystal shell including zinc, tellurium, and selenium, wherein the quantum dot does not include cadmium, and the semiconductor nanocrystal shell has a mole ratio of tellurium to selenium of less than about 0.025:1, a composition including the quantum dot, a quantum dot-polymer composite, a patterned layer including the composite, and an electronic device including the patterned layer.

Abstract: Described are compounds, compositions, and methods that include a nitrogen- and oxygen-containing aromatic compound, such as an aminophenol-based compound, which can be used for inhibiting polymerization of a monomer (e.g., styrene) composition. The compound includes a tertiary amine group wherein the nitrogen is attached to carbon-containing groups, and at least one of oxygen atom separated from the nitrogen by one or more carbon atoms. The antipolymerant can provide excellent antipolymerant activity in a monomer-containing composition.

Abstract: Liquid-crystal polymer is composed of the following repeating units: 10 mol % to 35 mol % of 10 mol % to 35 mol % of 10 mol % to 50 mol % of and 10 mol % to 40 mol % of 10 mol % to 40 mol % of or a combination thereof. Each of AR1, AR2, AR3, and AR4 is independently AR5 or AR5-Z-AR6, in which each of AR5 and AR6 is independently or a combination thereof, and Z is —O—, or C1-5 alkylene group. Each of X and Y is independently H, C1-5 alkyl group, CF3, or wherein R2 is H, CH3, CH(CH3)2, C(CH3)3, CF3, or n=1 to 4; and wherein R1 is C1-5 alkylene group.

Abstract: The present invention relates in part to a lignin composition and a method of fabricating a lignin composition. The invention also relates in part to a method of using a lignin composition to adsorb onto a petrochemical oil comprising the steps of providing a solution of lignin in an alcohol, providing an oil on a liquid surface, contacting the oil with the solution of lignin in an alcohol, adsorbing the lignin to the oil, and removing the adsorbed oil from the surface of the liquid.

Abstract: A fluoropropene composition comprising E-1,3,3,3-tetrafluoropropene, 1,1,3,3,3-pentafluoropropene, and 2,3,3,3-tetrafluoropropene, wherein the total amount of 1,1,3,3,3-pentafluoropropene and 2,3,3,3-tetrafluoropropene is 1.0 wt. % or less, based on the total weight of the fluoropropene composition. A method of producing the fluoropropene, composition and methods for using the fluoropropene composition are also disclosed.

Abstract: There is provided a thermosetting material with which the heat-dissipating properties of a cured product can be considerably heightened and the mechanical strength of the cured product can also be heightened. The thermosetting material according to the present invention includes a thermosetting compound, a thermosetting agent, boron nitride nanotubes, and an insulating filler not being a nanotube.

Abstract: The present disclosure relates to subterranean formation operations and, more particularly, to embedded treatment fluid additives for use in subterranean formation operations. The embedded treatment additives may comprise an aqueous-soluble downhole reactive material embedded in a crosslinked polymeric solution to delay the reactivity of the aqueous-soluble downhole reactive material, thereby forming the embedded treatment additive, wherein the aqueous-soluble downhole reactive material is a solid.

Abstract: A composition of matter including a mono-facial polymer-grafted graphene particle and an aqueous-based drilling fluid is provided. In the composition, a first side of the graphene particle has a grafted polymer. A method of lubricating a tool surface using the composition of matter is also provided. The method includes providing an aqueous-based drilling fluid, the aqueous-based drilling fluid having a mono-facial polymer-grafted graphene particle, and introducing the aqueous-based drilling fluid into a wellbore such that it contacts a tool surface to form a coated tool. A drilling tool having a mono-facial polymer-grafted graphene particle adhered to its surface is also provided.

Abstract: A drilling fluid composition comprising a continuous phase and a disperse phase, the continuous phase comprising fatty acid methyl esters derived from soy oil, and sunflower lecithin as an emulsifier. A method for increasing the electrical stability of a drilling fluid composition.

Abstract: Well treatment fluids may include solid particles comprising one or more components selected from the group consisting of urea, ammonium nitrate, ammonium chloride, barium hydroxide, and ammonium thiocyanate. These well treatment fluids may also include a carrier fluid, which may be an aqueous polymeric fluid, an oil, or combinations thereof. The aqueous polymeric fluid may include a polymer selected from the group consisting of guar gum, hydroxypropyl guar, carboxymethyl hydroxypropyl guar, cellulose, or polyacrylamide. The oil may include a material selected from the group consisting of diesel, mineral oil, and wax. Methods for reducing an acid carbonate reaction in a carbonate formation may include pumping a composition of solid particles into a formation; releasing the solid particles from the capsules or emulsion within the formation; and injecting an acid following the releasing step or during pumping, wherein the acid carbonate reaction is carried out at a reduced reaction rate.

Abstract: A method and system for corrosion control and scale control in water supply for injection, including specifying a corrosion inhibitor for squeeze treatment of a water supply well, specifying a scale inhibitor that can form a complex with the corrosion inhibitor, pumping the corrosion inhibitor and the scale inhibitor through a wellbore of the water supply well into an aquifer in a subterranean formation, forming the complex of the corrosion inhibitor and the scale inhibitor, and pumping water from the water supply well to an injection well for injection, the water including the scale inhibitor released from the complex in the aquifer and the corrosion inhibitor released from the complex in the aquifer.

Abstract: A surfactant of formula (I) wherein each of R1 and R2 are independently a hydrogen, an optionally substituted alkyl, an optionally substituted cycloalkyl, or an optionally substituted arylalkyl, R3 and R4 are independently an optionally substituted alkyl, an optionally substituted cycloalkyl, or an optionally substituted arylalkyl, x is an integer in a range of 2-8, y is an integer in a range of 1-15, z is an integer in a range of 4-10, n is an integer in a range of 2-5, and A is one of a carboxybetaine group, a sulfobetaine group, or a hydroxy sulfobetaine group. An oil and gas well servicing fluid containing the surfactant and methods of servicing an oil and gas well are also described.

Abstract: A method for the subterranean regeneration of CO2-philic solvents and the sequestration of carbon dioxide may include exposing the CO2-philic solvent to a carbon dioxide-containing gas in an absorber to allow the CO2-philic solvent to absorb at least a portion of the carbon dioxide in the carbon dioxide-containing gas, thereby producing a CO2-containing solution. The CO2-containing solution may be supplied to one or more porous rock fractures via one or more injection conduits in fluid communication with the one or more porous rock fractures. The CO2-containing solution may be heated via heat provided by one or more rock fractures in order to release at least a portion of the absorbed carbon dioxide into the one or more rock fractures and thereby regenerate the CO2-philic solvent.

Abstract: A method for removing liquid buildup in gas wells may include introducing a first aqueous solution and a second aqueous solution into the wellbore such that the first aqueous solution and the second aqueous solution may intermix within the wellbore. The first aqueous solution may contain a nitrogen-containing compound and the second aqueous solution may contain a nitrite-containing compound and a foaming agent. The method may further include maintaining the intermixed solution in the wellbore such that gas, heat, and foam may be generated, and removing the excess fluid from the wellbore. Furthermore, the method may include introducing an acid or acid precursor into the wellbore, releasing an acid from the acid precursor into the intermixed solution, and maintaining the acid with the intermixed solution in the wellbore to adjusted the pH of the intermixed solution to less than 7.0.

Abstract: A composition for a fracturing fluid may include a chelating agent, a polymeric gelling agent, and a base fluid. The base fluid in the fracturing fluid composition may be a produced fluid having a hardness content of at least 7,000 ppm. Method for treating a hydrocarbon-bearing formation may include introducing a fracturing fluid in the hydrocarbon-bearing formation. The fracturing fluid contains a chelating agent, a polymeric gelling agent, and a base fluid. The base fluid may be a produced fluid that has a hardness content of at least 7,000 ppm. The fracturing fluid may have a viscosity of at least 200 cp at 150° F., 100 1/s shear rate, and 300 psia when tested using model 5550 HPHT rheometer. After contacting the hydrocarbon-bearing formation, the viscosity of the fracturing fluid may drop near a range of 1 cP to 5 cP.

Abstract: This disclosure relates to methods of hydraulic fracturing that may include passing a fracturing fluid through a wellbore into a subterranean formation, wherein the fracturing fluid comprises a flowback enhancer composition in an amount of from 0.10 gallon per 1000 gallons of fluid (gpt) to 10 gpt based on the total volume of fracturing fluid, hydraulically fracturing the subterranean formation with the fracturing fluid, at least partially separating the fracturing fluid from the hydrocarbons to yield a recovered fracturing fluid. The flowback enhancer composition can include a solvent mixture comprising an aqueous solution, at least one unsaturated ester, and at least one alcohol; a surfactant mixture comprising at least one secondary alcohol ethoxylate and at least one castor oil ethoxylate; and one or more particles having a widest length of from 1 nanometer to 200 nanometers.

Abstract: The present invention provides a proppant or proppant mixture having insert materials configured for providing a mechanical or physical function in a well to hold open fissures or pathways created in formations caused by well fracking to allow a release of a hydrocarbon from the well, the insert materials being configured at least partly with beads having a functionalized polymer so as to form functionalized polymer proppants that are configured to respond to the hydrocarbon or other composition of matter released from the well, including water, and provide at least one chemical taggant containing an indication about the hydrocarbon or other composition of matter released from the well. The functionalized polymer may include a dual-monomer structure.

Abstract: Inorganic electrochromic materials and methods of manufacturing utilize a reactive PDC magnetron, where co-sputtering synthesis of electrochromic materials are performed: (1) directly from carbide targets; (2) from relevant transition metals and graphite target, as well as non-metal elements such as Si, Ge, P, B, etc.; (3) directly from composite targets (fine powder mixture of transition metals, non-metal elements and graphite powder). Sputtering may be performed instantly from 1 to 4 targets. For co-sputtering, a combination of gas mixtures may be used: Ar/O2/N2, Ar/H2/N2/O2, Ar/NH3/O2, Ar/CO/N2/O2, Ar/CO/H2/N2/O2, Ar/CH4/N2/O2 and Ar/NH3/CO/N2/O2. This allows obtaining electrochromic materials with increased electronic and ionic conductivity, higher coloration and good cycling (lifetime). Moreover, different tints of blue as well as gray, black and brown colors neutral to the eye may be obtained. Sputtered electrochromic films were additionally improved by “thermo-splitting” pre-intercalated thin films.

Abstract: A process for producing a polymerizable composition for optical materials of the present invention includes a step A of mixing together a polyisocyanate compound (i), a polymer (ii) represented by General Formula (ii), a photochromic compound (iii), and an internal release agent (iv), a step B of mixing a mixed solution obtained by the step A with a polythiol compound (v), and a step C of further mixing a mixed solution obtained by the step B with a polymerization catalyst (vi) so as to obtain a polymerizable composition for optical materials, wherein in the step A, the internal release agent (iv) is added so that a content thereof in the polymerizable composition for optical materials is 500 to 3,000 ppm, and in the step C, the polymerization catalyst (vi) is added so that a content thereof in the polymerizable composition for optical materials is 120 to 500 ppm. R1A1—R2—A2—R3]n??(ii).

Abstract: A shale pyrolysis system includes a retort with a first side and a second side. The second side is opposite the first side and the first side and the second side include descending angled surfaces at alternating angles to produce zig-zag motion of shale descending through the retort. Corners of the retort that change direction of the shale are rounded. The system includes steam distributors coupled to the first side and collectors coupled to the second side to produce crossflow of steam and heat across the descending shale from the first side to the second side, and a steam temperature control subsystem coupled to the steam distributors and configured to deliver higher-temperature steam to one or more upper sections of the retort and lower-temperature steam to one or more lower sections of the retort.

Abstract: A process for the preparation of aromatic compounds from a feed stream containing biomass or mixtures of biomass, the process comprising: a) subjecting a feed stream containing biomass or mixtures of biomass to a process to afford a conversion product comprising aromatic compounds; b) recovering the aromatic compounds from said conversion product; c) separating a higher molecular weight fraction comprising polyaromatic hydrocarbons (PAH) from a lower molecular weight fraction comprising benzene, toluene and xylene (BTX) by distillation; d) reducing at least part of said higher molecular weight fraction to obtain a reduced fraction comprising polycyclic aliphatics (PCA); and e) subjecting the higher molecular weight fraction obtained in step c), the reduced fraction obtained in step d), or a mixture thereof, to a process to obtain lower molecular weight aromatics (BTX).

Abstract: A process for converting crude oil may comprise contacting a crude oil with one or more hydroprocessing catalysts to produce a hydroprocessed effluent and contacting the hydroprocessed effluent with a fluidized catalytic cracking (FCC) catalyst composition in an FCC system to produce cracked effluent comprising at least olefins. The crude oil may have an API gravity from 30 to 35. The FCC system may operate at a temperature of greater than or equal to 580° C., a weight ratio of the FCC catalyst composition to the crude oil of from 2:1 to 10:1, and a residence time of from 0.1 seconds to 60 seconds. The FCC catalyst composition may comprise ultrastable Y-type zeolite (USY zeolite) impregnated with lanthanum; ZSM-5 zeolite impregnated with phosphorous; an alumina binder; colloidal silica; and a matrix material comprising Kaolin clay.

Abstract: This disclosure relates to a procedure, which through the application of a catalyst in homogeneous phase, allows the transformation of heavy hydrocarbons (vacuum residue, atmospheric residue, heavy and extra-heavy crudes) into hydrocarbons of lower molecular weight, characterized because after its application, the hydrocarbons obtain greater API gravity, lower kinematic viscosity and different composition by hydrocarbon families (SARA) that increases the proportion of saturated and aromatic resins and asphalts. The sulphur and nitrogen content is also reduced, resulting in higher yields to high commercial value distillates and a lighter product as compared to the original crude.

Abstract: A process for upgrading crude oil may include combining crude oil and feed water in a supercritical water unit to produce a first upgraded output, separating the first upgraded output in a first gas-water-oil separator to produce a first gas effluent, a first water effluent, and a first oil effluent, separating the first water effluent in a first water treatment unit to produce a rejected water stream and a recycle water stream, combining the first oil effluent and the rejected water stream in a nearcritical water unit to produce a second upgraded output, and recycling at least a portion of the recycle water stream for introduction into the supercritical water unit. A system for upgrading crude oil may include a supercritical water unit, a first gas-water-oil separator disposed downstream of the supercritical water unit, a first water treatment unit disposed downstream of the first gas-water-oil separator, and a nearcritical water unit.

Abstract: A method for producing a diesel having improved cold flow properties, the method comprising the steps of introducing a crude oil to a distillation column, separating the crude oil in the distillation unit to produce a light gas oil, and a light vacuum gas oil, where the light gas oil has a T95% cut point in the range between 300 deg C. and 340 deg C., where the light vacuum gas oil has a T95% cut point in the range between 400 deg C. and 430 deg C., processing the light vacuum gas oil in the supercritical water unit to produce an upgraded vacuum gas oil, separating the upgraded vacuum gas oil in the fractionator to produce an upgraded light fraction, an upgraded light gas oil, and upgraded heavy fraction, introducing the upgraded light gas oil into a diesel pool, and blending the light gas oil into the diesel pool.

Abstract: The present invention describes a method to produce high purity hydrocarbon materials from renewable sources. The produced materials are chemically indistinguishable from highly refined mineral oils and/or synthetic hydrocarbons. These renewable hydrocarbon materials can be used as a drop-in replacement for mineral and synthetic hydrocarbon base oils, process fluids, white oils in products such as lubricants, rubber, personal care, pharma.

Abstract: The present application relates to a method for treating a petrol containing sulphur compounds, olefins and diolefins, the method comprising the following steps: a) a step of hydrodesulphurisation in the presence of a catalyst comprising an oxide support and an active phase comprising a group VIB metal and a group VIII metal from, b) a step of hydrodesulphurising at least one portion of the effluent from step a) at a higher hydrogen flow rate/feed ratio and a temperature higher than those of step a) without removing the H2S formed in the presence of a catalyst comprising an oxide support and an active phase consisting of at least one group VIII metal, c) a step of separating the H2S formed in the effluent from step b).

Abstract: A method of processing a hydrocarbon feedstock may comprise hydrotreating the hydrocarbon feedstock in a low-severity hydrotreater to produce a first effluent and hydrotreating the first effluent, or a portion thereof, in a high-severity hydrotreater to produce a low contaminant product. The low-severity hydrotreater may operate at a catalyst volume of less than 60% of a catalyst volume of the high-severity hydrotreater. The low-severity hydrotreater may operate at a hydrogen partial pressure of at least 5 bar lower than the hydrogen partial pressure in the high-severity hydrotreater. The low-severity hydrotreater may operate at a weighted average bed temperature (WABT) of at least 5° C. less than the WABT of the high-severity hydrotreater.

Abstract: A process for the production of ultralow aromatic specialty distillate from different refinery streams particularly high sulfur streams. The process produces de-aromatized distillates with benzene content below 1 ppmw. Hydrocarbon feedstock having boiling temperature in the range of 90 and 350° C., preferably 140 and 320° C. The hydrocarbon feedstocks are obtained from any petroleum-refinery or bio-refinery or any other source producing hydrocarbon streams.

Abstract: A method of processing a hydrocarbon feed may comprise fractionating the hydrocarbon feed into a light stream and a heavy stream, where the light stream includes hydrocarbons boiling at less than 370° C., and the heavy stream includes hydrocarbons boiling at greater than greater than 370° C., hydrotreating the heavy stream to form a hydrotreated heavy stream, feeding the light stream to a first Fluid Catalytic Cracking (FCC) reaction zone, thereby producing a light product stream which includes light olefins, and feeding the hydrotreated heavy stream to a second Fluid Catalytic Cracking (FCC) reaction zone, thereby producing a heavy product stream which includes light olefins, where the first FCC reaction zone operates under more severe operating conditions than the second FCC reaction zone.

Abstract: A process for converting crude oil may comprise contacting a crude oil with one or more hydroprocessing catalysts to produce a hydroprocessed effluent and contacting the hydroprocessed effluent with a fluidized catalytic cracking (FCC) catalyst composition in an FCC system to produce cracked effluent comprising at least olefins. The crude oil may have an API gravity from 25 to 29. The FCC system may operate at a temperature of greater than or equal to 580° C., a weight ratio of the FCC catalyst composition to the crude oil of from 2:1 to 10:1, and a residence time of from 0.1 seconds to 60 seconds. The FCC catalyst composition may comprise ultrastable Y-type zeolite (USY zeolite) impregnated with lanthanum; ZSM-5 zeolite impregnated with phosphorous; an alumina binder; colloidal silica; and a matrix material comprising Kaolin clay.

Abstract: According to one embodiment of the present disclosure, a method of processing a hydrocarbon feed includes fractionating the hydrocarbon feed into a light stream and a heavy stream; hydrotreating the heavy stream to form a hydrotreated heavy stream; feeding the light stream and the hydrotreated heavy stream to a single Fluid Catalytic Cracking (FCC) reaction zone, thereby producing a product stream which includes light olefins. The light stream may be exposed to more severe FCC cracking conditions than the heavy stream, within the same FCC reaction zone. The single FCC reaction zone may be operated in a down-flow configuration and the FCC may be operated under high severity conditions. The light stream may include hydrocarbons boiling at less than 371° C. and the heavy stream may include hydrocarbons boiling at greater than 371° C.

Abstract: According to one embodiment of the present disclosure, a method of processing a hydrocarbon feed may comprise fractionating the hydrocarbon feed into a light stream, a middle stream, and a residue stream, hydrotreating the residue stream to form a hydrotreated residue stream; and feeding the light stream, middle stream, and the hydrotreated residue stream to a single Fluid Catalytic Cracking (FCC) reaction zone, thereby producing a product stream comprising light olefins. The light stream and the hydrotreated residue streams may be exposed to more severe FCC cracking conditions than the middle stream, within the same FCC reaction zone. The single FCC reaction zone may be operated in a down-flow configuration and the single FCC reaction zone may be operated under high severity conditions.

Abstract: Embodiments of the present disclosure are directed to a method of processing a hydrocarbon feed includes fractionating the hydrocarbon feed into a light stream and a heavy stream, hydrotreating the heavy stream to form a hydrotreated heavy stream, combining the light stream and the hydrotreated heavy stream to form a upgraded feed stream, and feeding the upgraded feed stream to a single Fluid Catalytic Cracking (FCC) reaction zone, thereby producing a product stream comprising light olefins. The light stream may comprise hydrocarbons boiling at less than 540° C. and the heavy stream may comprise hydrocarbons boiling at greater than 540° C. The FCC reaction zone may be operated in a down-flow configuration and the FCC may be operated under high severity conditions.

Abstract: An ecofriendly corrosion inhibitor composition and a method for inhibiting corrosion on a metal surface with the ecofriendly corrosion inhibitor composition are provided. The ecofriendly corrosion inhibitor composition includes 10-30 weight % of fatty acids derived from waste vegetable oils and 70-90 weight % of heavy aromatic naphtha. The fatty acids derived from waste vegetable oils include oleic acid, linoleic acid, and palmitic acid. In the method, the ecofriendly corrosion inhibitor composition is added to a hydrocarbon fluid exposed to the metal surface and the corrosion inhibitor composition inhibits corrosion on the metal surfaces.

Abstract: An anti-fouling composition has been developed that provides an advantageous reduction in the fouling of a structural part in a petroleum-refining system including reducing coking reactions and inhibiting deposition of solids in equipment and lines used for crude oil production and processing. The anti-fouling compositions contain a resin comprising an alkyl phenol-aldehyde resin, a polyolefin comprising a polyalkylene ester, polyolefin amide alkeneamine, polyethylene polyamine, polyalkyleneimine, or a combination thereof; and optionally, a polyalkylene imide, an amine-substituted polyalkylene imide, or a combination thereof; and optionally, N,N?-disalicylidene-1,2-propanediamine.

Abstract: According to embodiments disclosed herein, a method of reducing corrosion during petroleum transportation, petroleum storage, or both, may comprise inputting a corrosion inhibitor formulation into a petroleum pipeline, a petroleum storage tank, or both, wherein the corrosion inhibitor formulation consists essentially of solvent and a pyridinium hydroxyl alkyl ether compound.

Abstract: An energy efficient process for NGL recovery and production of compressed natural gas (CNG) in which natural gas is fed to a first gas separation membrane-based separation stage where it is separated into a permeate and a retentate. The high C3+ concentration first stage permeate is chilled and separated to provide liquid phase NGL and a gaseous phase. The first stage retentate is separated at a second gas membrane-based separation stage to produce a retentate meeting pipeline specifications for CNG (including hydrocarbon dewpoint) and a permeate that is recycled to the first stage. The gaseous phase, constituting a low BTU fuel, may be used in on-site power generation equipment and/or in internal combustion engines. The second stage permeate (and optionally the third stage retentate) is (are) recycled back to the first stage to enhance the production of NGL and CNG.

Abstract: 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.

Abstract: A process of making a fuel product from a non-combustible high protein organic material such as a biological by-product or waste material. The moisture content of the high protein organic material is mechanically reduced and dried to reduce the moisture content to less than ten percent (10%). The high protein organic material is pulverized to a particle size of less than about 2 mm. The high protein organic waste material is fed into a combustion chamber and separated during combustion such as by spraying high protein organic waste material within the combustion chamber. Temperature and combustion reactions within the combustion chamber are controlled by controlling the moisture in the combustion atmosphere and energy injections at or downstream of the combustion chamber. The concentration of protein thermal decomposition by-products, temperature, and residence time and/or additions of energy plasma within the combustion chamber environment are controlled to degrade hazardous polyfluoro compounds.

Abstract: Systems and methods associated with biomass decomposition are generally described. Certain embodiments are related to adjusting a flow rate of a fluid comprising oxygen into a reactor in which biomass is decomposed. The adjustment may be made, at least in part, based upon a measurement of a characteristic of the reactor and/or a characteristic of the biomass. Certain embodiments are related to cooling at least partially decomposed biomass. The biomass may be cooled by flowing a gas over an outlet conduit in which the biomass is cooled, and then directing the gas to a reactor after it has flowed over the outlet conduit. Certain embodiments are related to systems comprising a reactor and an outlet conduit configured such that greater than or equal to 75% of its axially projected cross-sectional area is occupied by a conveyor.

Abstract: The present invention is toward a base oil or lubricant additives, methods of using the same, lubricant compositions including the same, and methods of forming the lubricant compositions. A base oil or lubricant additive has Structure I or Structure II as described herein.

Abstract: Provided is a lubricating oil composition including a lubricating oil additive and a lubricating oil, the lubricating oil additive having nanodiamonds, of which a surface is hydrophobically modified by a surface treatment, dispersed in a base oil. The lubricating oil composition retains dispersibility over a long period of time and thus can ensure storage stability. Machines to which the lubricating oil composition is applied may have improved abrasion resistance as well as improved fuel consumption and reduced noise, and high thermal conductivity of the lubricating oil composition may also increase cooling efficiency and the service life of machines.

Abstract: An ultrasonic-assisted heat press machine, includes a frame, a material tank, an extruder, an ultrasonic wave generator, and a heater. The material tank is disposed on the frame and includes a cavity for accommodating an oil-bearing raw material. The extruder is extended in the cavity. The ultrasonic wave generator is disposed on the frame and adjacent to the material tank. The heater is disposed on the frame and adjacent to the material tank. The heater is configured to produce heat to heat the cavity and the ultrasonic wave generator, and regulate the working frequency of the ultrasonic wave generator. When in use, the heater, the extruder, and the ultrasonic wave generator cooperate to separate oil from the oil-bearing raw material in the material tank.

Abstract: A cleaning composition that includes a first cleaning agent and a second cleaning agent. The first cleaning agent is water-soluble at room temperature and the second cleaning agent is water-insoluble at room temperature. Further, the first cleaning agent and the second cleaning agent are in a total amount of about 15 wt. % to about 30 wt. %, wherein the first cleaning agent and the second cleaning agent are alkyl polyalkylene glycol ether Guerbet surfactants having a hydrophilic-lipophilic balance of at least 10.5 and a formula RO(LO)k(CH2CH2O)mH, wherein R is a branched C8-C12 alkyl group, L is CH2CH2CH2 or CH2CH2CH2CH2, k is from 1-2, m is from 2 to 14, and the LO and CH2CH2O groups are in random or block order. A blend of the first cleaning agent and the second cleaning agent has a hydrophilic-lipophilic balance ranging from about 10.5 to about 12.5.