Abstract: Disclosed are a room temperature curable quick-setting high-strength alkali-activated fly ash (AAFA) cementitious material and a preparation method thereof, belonging to the technical field of building materials. The raw materials include: in parts by mass, 30-50 parts of undisturbed fly ash, 50-70 parts of highly reactive ultra-fine fly ash, and 12-18 parts of sodium hydroxide. Specifically, the AAFA with fast setting and high strength for room temperature curing is prepared by pretreatment of fly ash with sodium hydroxide exciter, based on a premise that the raw material system and preparation process are simplified and feasible.

Abstract: A methyl ethyl hydroxyalkyl cellulose (MEHEC), process for making the MEHEC, and a powder containing the MEHEC are disclosed. The MEHEC is provided with a DSmethyl from 1.5 to 2.5, a DSethyl from 0.005 to 0.15, and a MSalkylene-oxide from 0.005 to 0.2. The methyl ethyl hydroxyalkyl cellulose optionally includes an anti-oxidant. The MEHEC optionally does not have a combination of a DSmethyl of 2.2 or 1.8, a DSethyl of 0.05 or 0.1, and a MSalkylene-oxide of 0.1 and does not have a combination of a DSmethyl of 2.5 or 2.0, a DSethyl of 0.1, and a MSalkylene-oxide of 0.05. The MEHEC has very good biostability and is suitable for use in the building industry.

Abstract: Embodiments of treating fluid comprising hydrocarbons, water, and polymer being produced from a hydrocarbon-bearing formation are provided. One embodiment comprises adding a concentration of a viscosity reducer to the fluid to degrade the polymer present in the fluid and adding a concentration of a neutralizer to the fluid to neutralize the viscosity reducer in the fluid. The addition of the concentration of the viscosity reducer is in a sufficient quantity to allow for complete chemical degradation of the polymer prior to the addition of the concentration of the neutralizer in the fluid such that excess viscosity reducer is present in the fluid. The addition of the concentration of the neutralizer is sufficiently upstream of any surface fluid processing equipment to allow for complete neutralization of the excess viscosity reducer such that excess neutralizer is present in the fluid prior to the fluid reaching any of the surface fluid processing equipment.

Abstract: The current method comprises producing a loss control blend by selecting blend ingredients that contribute to thixotropy of the blend, density of the blend, and compressive strength of the set blend, wherein at least one of the blend ingredients contributes positively to all three of these attributes.

Abstract: According to one or more embodiments, sulfate ions may be removed from seawater to form an injection fluid by a method including passing the seawater and formation water to a mixing tank. The seawater may comprise sulfate ions. The formation water may comprise barium ions. The seawater and formation water may be passed to the mixing tank in a ratio determined by a computerized geochemical model. The method may further include mixing the seawater and formation water to form a mixed fluid and passing the mixed fluid to a clarifier, where a barium sulfate precipitate may be formed and at least a portion of the barium sulfate precipitate may be separated from the mixed fluid. The method may further include passing the mixed fluid to a microfiltration system, where at least a portion of the barium sulfate precipitate may be removed from the mixed fluid to form an injection fluid.

Abstract: A method of polymer flooding within a carbonate formation the method comprising: injecting a treatment fluid composition into a wellbore, the treatment fluid composition comprising: a base fluid, and a viscosifier comprising a branched block copolymer wherein the branched block copolymer is a crosslinked, polymerized reaction product of crosslinker C and monomer A and monomer B and monomer D; and increasing hydrocarbon production from the wellbore.

Abstract: A thermoplastic elastomer for profile control and water shutoff is prepared from the following raw materials in parts by weight: 8-10 parts of a component A, 1-3 parts of a strong acid, 1-3 parts of a hydrophobic modifier and 100-105 parts of water. The component A is one of polyethylene glycol, polyvinylether, polyvinyl alcohol, copolymer of acrylamide and acrylonitrile. The strong acid is one of concentrated hydrochloric acid and concentrated sulfuric acid. The hydrophobic modifier is any one of formaldehyde, acetaldehyde, propionaldehyde, butyraldehyde, ?-propiolactone, ?-butyrolactone, ?-valerolactone, methyltriacetylsilane, methyltrimethylsilane, butyl acrylate and ethylene glycol dimethacrylate. The thermoplastic elastomer for profile control and water shutoff provided by the disclosure has the advantages of one-step preparation and molding, strong deformation capability, temperature resistance, salt tolerance, strong stability and the like, and is suitable for large-scale production and application.

Abstract: A method for producing a bulk material consisting substantially of foamed or blown mineral or oxide particles by thermal treatment of a bulk material of basic particles, characterized in that the thermal treatment includes transport of a transversely conveyed or horizontal layer or of a free flow of the bulk material through a radiation field, the substantial active component of which lies in the near infrared range (NIR), and which has a power density of at least 50 kW/m2.

Abstract: Drilling fluid compositions include an emulsifier having a generic structure A, structure B, or a combination thereof. Structure A includes an amide (e.g., amic acid group) and structure B includes a cyclic imide. The emulsifier of the emulsifier system is formed by reacting a fatty oil amine (e.g., oleyl amine), with a cyclic anhydride (e.g., succinic anhydride) in the absence of diluent or in a diluent that does not react with the starting materials. The reaction takes place via application of a stepwise increase in temperature. An emulsifier based on structure A is formed when the reaction temperature is maintained at 50 to 100° C. for 1 to 3 hours. A further increase in reaction temperature (e.g., up to 200° C.) can include water elimination which results predominately in the formation of a molecule represented by structure B.

Abstract: A drilling fluid may include a carrier and a lubricant composition. The lubricant composition includes ethylene bottoms heavy pyrolysis oil. For example, the heavy pyrolysis oil may be bottoms of a fractionated fuel oil product separated from ethylene gas produced by a cracking of a hydrocarbon feedstock in a furnace.

Abstract: Multilayered electrolyte compositions and methods for their manufacture and use are described. The compositions can have an inner core and one or more coating layers. The compositions can contain at least one chlorine source and at least one citrate salt. The compositions are useful for treating water to improve safety, among other things.

Abstract: The invention is directed to delayed gelation agents comprising a degradable polymeric cage containing therein one or more gelation agents. The cage degrades in situ, e.g, in an oil reservoir, thus releasing the gelation agent(s), which can then crosslink second polymers in situ to form a gel.

Abstract: A nano-organosilicon film-forming and hydrophobic shale surface hydration inhibitor is obtained by performing hydrophobic modification for nano-particles through long-chain organosilicon together with a surface-active agent. A preparation method of the said hydrophobic shale surface hydration inhibitor comprises steps as follows: nano-particles are added to the solvent under stirring conditions, and then an ultrasonic dispersion is performed; upon the end of the ultrasonic dispersion, the reaction system is adjusted to a pH of 9-11 to obtain mixed solution A; a long-chain organosilicon solution is then dropwise added to the mixed solution A for reaction under stirring conditions to obtain mixed solution B; a surface-active agent is added to the mixed solution B for reaction under stirring conditions; upon the reaction is finished, part of the solvent is removed to obtain the inhibitor.

Abstract: An asphalt pavement modification system and method for improving aging resistance of asphalt pavement and a method of manufacturing reclaimed asphalt pavement. The asphalt pavement modification system and method include using one or more antioxidants and one or more recycling agents in a blended binder to provide improved short term and long term performance of the asphalt pavement. The method of manufacturing reclaimed asphalt pavement includes mixing at least one antioxidant with at least one recycling agent to form a binder that constitutes a portion of the reclaimed asphalt pavement. One of the antioxidants may be zinc diethyldithiocarbamate.

Abstract: A method of removing a sulfate scale from a surface is provided. The method includes contacting the sulfate-comprising scale with a conversion solution including 1 to 10 wt. % of an alkali metal carbonate, 0.5 to 10 wt. % of a borate salt or hydrate thereof, and 0.5 to 2.5 wt. % of a base to produce a carbonate-comprising scale. The method further includes exposing the carbonate-comprising scale with an acid solution including 2.5 to 25 wt. % of an acid.

Abstract: A hypochlorous acid disinfectant and its production method. The disinfectant is prepared by weight in a total of 100% as chlorine powder (chlorine compounds including sodium hypochlorite or calcium hypochlorite) of 20 to 45%, adding sodium dihydrogen phosphate or citric acid, or ingredients or raw materials with acidic pH of 15 to 40% as a main ingredient, a desiccant of 15 to 20%, excipients of 3 to 8%. The method includes: stirring the chlorine powder with the desiccant; adding the sodium dihydrogen phosphate, the citric acid, or the ingredients or raw materials with acidic pH in order; and adding the excipient while stirring for 20 to 30 minutes until completely uniform to prepare the hypochlorous acid (powder) disinfectant. According to the method, a hypochlorous acid tablet disinfectant can be prepared.

Abstract: A method for in situ acid stimulation of a subterranean formation that contains a hydrocarbon reservoir may include contacting the formation with an acidizing fluid comprising an aqueous fluid, a sulfonyl chloride, and a mutual solvent, wherein upon exposure to formation temperatures, the sulfonyl chloride and aqueous fluid hydrolyze the sulfonyl chloride, thereby producing hydrochloric acid.

Abstract: The present invention relates to a composition for an enhanced oil recovery process, said composition comprising (a) one or more anionic cocogem surfactants; b) one or more surfactants based on nonionic vegetable fatty acids (or their synthetic analogues); c) optionally one or more, preferably commercially available, co-surfactants; d) optionally one or more agents with phase transfer property, preferably an alcohol; and e) polyacrylamide as a flow modifier.

Abstract: The present invention provides a concrete vacuum tube segment for a hyper-speed transportation system using ultra-high performance concrete (UHPC) and a manufacturing method thereof. A concrete vacuum tube segment for a hyper-speed transportation system can be easily manufactured using UHPC, in which shrinkage and structural cracking do not occur due to mixing a binder and a short fiber to secure airtightness on the basis of a maximum fill theory, and accordingly, shrinkage of the concrete vacuum tube segment can be reduced even in a partial-vacuum state in which the magnitude of drying shrinkage is very small and quick drying occurs; when mixing the UHPC, an antifoaming agent is mixed and a circular vacuum pump is used to remove generated entrapped air to minimize the entrapped air; and a capsule-type crack healing material, which is able to repair fine cracks, is compacted to secure airtightness of the concrete vacuum tube segment.

Abstract: A method includes selecting a model for a simulation of hydrocarbon recovery from a reservoir having a plurality of fractures during injection of an injected gas into the plurality of fractures. Selecting the model includes determining a flux ratio of a convection rate to a diffusion rate for the reservoir, determining whether the flux ratio is less than a threshold, and in response to the flux ratio being less than the threshold, selecting the model that includes diffusion. Selecting the model includes performing the simulation of the hydrocarbon recovery from the reservoir based on the model.