Abstract: A method of cementing a wellbore comprises combining a liquid additive with a cement slurry, the liquid additive comprising a metal gluconate, an alkali metal or an alkaline earth metal salt, an alkanolamine, a dispersant, and water to form a cementing composition; injecting the cementing composition into the wellbore; and allowing the cementing composition to set.

Abstract: Dual cation hydrate inhibitor compositions and methods of using such compositions to, for example, inhibit the formation of gas hydrate agglomerates are provided. In some embodiments, such methods include introducing a hydrate inhibitor composition into a fluid, wherein the hydrate inhibitor composition includes at least one compound having the structural formula: wherein each of R1, R2, and R3 is independently a C1 to C6 hydrocarbon chain, wherein R4 is selected from the group consisting of hydrogen and any C1 to C50 hydrocarbon chain, wherein each of R5 and R6 is independently selected from the group consisting of hydrogen and a C1 to C50 hydrocarbon chain, wherein X? and Y? are counter anions, and wherein each of a and b is independently an integer from 1 to 10.

Abstract: A hydrocarbon production system comprises a base pipe; and a separator having a body with an inner surface defining a conduit, the inner surface being coated with a polymer blend comprising a hydrophilic component and a hydrophobic component, an inlet, a water outlet, and an oil outlet fluidly coupled to the base pipe.

Abstract: Described herein are methods of treating fluid comprising hydrocarbons, water, and polymer being produced from a hydrocarbon-bearing formation are provided. The method can include 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 viscosity reducer is buffered at a pH of 7 or less (e.g., at a pH of from 2 to 7, such as at a pH of from 3.5 to 7, or at a pH of from 5 to 7). 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.

Abstract: A method may include: providing a cleanout fluid comprising a single anionic surfactant, a single nonionic surfactant, and a solvent; preparing a cleanout pill by mixing the cleanout fluid with a brine; and displacing a fluid in a wellbore using the cleanout pill.

Abstract: Treatment fluids and methods of using a treatment fluid for minimizing fluid loss in a wellbore are disclosed. A method may comprise providing a drill-in fluid. The drill-in fluid may comprise an aqueous liquid, a base oil, a polyol, an emulsifying surfactant, and a solid bridging agent. The method may further comprise circulating the drill-in fluid through a drill-string and past a drill bit. The method may further comprise drilling in a reservoir section of a subterranean formation to extend a wellbore in the reservoir section the drill-in fluid is circulated therein.

Abstract: A method and system using the measured adsorption of a tracer substance leached from a flexible liner sealing a subterranean borehole to indicate the flow of fluid, typically water, past the borehole. The liner is provided with contaminant collectors. The liner is impregnated in its fabrication with a tracer substance. The tracer is leached from the liner as water flows past the liner in/from fractures in the surrounding geologic formation. The water containing any leached tracer may also flow past the collectors. The collectors adsorb the tracer relative to the amount of tracer leached from the liner and into the passing water, and the concentration of tracer in the flowing water is proportional to the amount of toluene leached from the liner. The tracer level in a collector is tested as an indication of the flow past the liner.

Abstract: A process for producing a base oil composition particularly adapted for use in oil-base drilling mud compositions. The process includes contacting drilling waste containing an oil-base mud phase with a solvent to produce a mixture of liquids and solids, separating the two phases, partially evaporating the liquids phase to produce an oil base composition substantially lacking low molecular weight carbon chain compounds and also lacking significant concentrations of benzene, toluene, xylene, and/or ethyl benzene, and having increased closed-cup flashpoint when compared to the oil-base mud phase in the drilling waste. The resulting base oil has enhanced health and safety characteristics for workers interacting with and otherwise exposed to the oil base composition during transporting, conditioning or using such compositions. The base oil produced and drilling methods using the recovered and recycled mud are also described.

Abstract: A method of treating a well comprising introducing a well treatment fluid into the well, and a well treatment fluid, are provided. The well treatment fluid comprises an aqueous base fluid, sepiolite clay, and a polymer component selected from the group of an acryloylmorpholine polymer, a polyvinylpyrrolidone polymer, and mixtures thereof. In one embodiment, for example, the method is a method of drilling a well. In this embodiment, the well treatment fluid is a drilling fluid.

Abstract: The present invention relates to a colloidal composition for stimulating the operation of high water-yield, natural gas, or petroleum-producing wells, which, when mixed with the water, forms a structured high viscosity barrier to exclude the water and to reduce the water/hydrocarbon volume proportion of the production, furthermore, at the time of use, in the proximity of the wells the residual oil sorbed on the surface of the hydrocarbon reservoir and/or the residual oil trapped in the pores of the hydrocarbon reservoir becomes compressible and recoverable. The colloidal composition comprises a vegetable oil reaction product based compound. Experiments with the new composition have demonstrated that it can be successfully used in a much wider range of parameters than before to form a barrier resulting in water displacement, as well as to mobilize and recover residual oil adhering to the well area.

Abstract: A method of drilling a wellbore includes pumping an oleaginous wellbore fluid into a wellbore, the oleaginous wellbore fluid including an oleaginous continuous phase; a non-oleaginous discontinuous phase; an emulsifier stabilizing the non-oleaginous discontinuous phase in the oleaginous continuous phase; an organophilic clay; a weighting agent; and a wetting agent having an HLB ranging from about 4 to 10.5 that it selected such that the oleaginous wellbore fluid has a 600 rpm dial value at 40° F. of less than about 300 and a 10 minute gel strength of less than about 40 lbf/100 ft2.

Abstract: Methods for treating a formation may include introducing components of a treatment solution into a wellbore such that the treatment solution contacts the formation to be treated, where the treatment solution may include urea, urease, a calcium ion source, one or more polysaccharides, a casein protein, a protease, an ionic compound, and a sugar, where the formation may have an amount of sand production before treatment and may be in fluid contact with the wellbore, and where an amount of sand production after treatment may be less than the amount of sand production before treatment. Consolidated sand structure compositions may include previously unconsolidated sand interlinked by inter-particle cementitious bonds comprising deposited calcium carbonate crystals, where the consolidated sand has a structural strength and the consolidated sand structure is porous to permit fluid flow through the composition.

Abstract: Methods of cementing include providing a geopolymer cement composition that includes a monophase amorphous hydraulic binder material (MAHBM), a metal silicate, an alkaline activator, and a carrier fluid, introducing the geopolymer cement composition into a subterranean formation, and allowing the geopolymer cement composition to set in the subterranean formation. The MAHBM includes silica or alumina core particulates coated with an amorphous calcium silicate hydrate.

Abstract: Provided is an injection fluid that may include a nanoemulsion having an oil phase dispersed in an aqueous phase, and non-superparamagnetic magnetic nanoparticles that are present in the dispersed oil phase. Further provided is a method for preparing an injection fluid that may include preparing a nanoemulsion from an aqueous phase and an oil phase having non-superparamagnetic magnetic nanoparticles therein, and may be used to form nanodroplets of the non-superparamagnetic magnetic nanoparticles. Further provided is a method for tracking movement of an injection fluid. The method may include introducing a tagged injection fluid into a hydrocarbon-containing reservoir, the tagged injection fluid may be a nanoemulsion that includes: an aqueous phase, an oil phase dispersed in the aqueous phase, and non-superparamagnetic nanoparticles that are present in the dispersed oil phase; and tracking the movement of the tagged injection fluid.

Abstract: Expansive cement compositions for use in subterranean wellbores that include a monophase amorphous hydraulic binder material (MAHBM). The MAHBM may include a plurality of particles having a silica core and an amorphous coating substantially surrounding the silica core. The coating may comprise, for example, a plurality of amorphous ?-dicalcium silicate hydrate nanoparticles or microparticles. The MAHBM may be used as an expansion agent in a cement composition or used as an expansive cement by itself.

Abstract: A hydrate inhibitor comprising a boronic acid moiety and associated methods and compositions.

Abstract: A method for exploiting a natural gas hydrate reservoir includes drilling a borehole entering the natural gas hydrate reservoir; perforating the borehole to form perforations; fracturing the natural gas hydrate reservoir via the perforations by using a gas containing calcium oxide powder having a particle size 0.001 to 10 mm to generate a fracture; and collecting natural gas released by the natural gas hydrate. The method is easy to operate, cost-effective, and suitable for commercial applications.

Abstract: A method for treating kerogen in a subterranean zone which includes the use of supercritical carbon dioxide or emulsions of liquid carbon dioxide and an aqueous fluid. The carbon dioxide or emulsions can further include oxidizers. The oxidizers can include inorganic oxidizers or organic oxidizers, for example an oxidizer including an organic cation and an oxidizing anion. Additional additives such as polymers, crosslinkers, clay inhibitors, scale inhibitors and corrosion inhibitors can further enhance the efficiency of the kerogen-treating carbon dioxide or emulsion.

Abstract: Non-aqueous drilling fluids may be removed from a wellbore or tubing nor casing within the wellbore by introducing into the well a biodegradable aqueous fluid comprising banana.

Abstract: A method for the stimulation of a hydrocarbon-bearing formation, said method comprising the steps of: providing a wellbore in need of stimulation; inserting a plug in the wellbore at a location slightly beyond a predetermined location; inserting a perforating tool and a spearhead or breakdown acid into the wellbore; positioning the tool at said predetermined location; perforating the wellbore with the tool thereby creating a perforated area; allowing the spearhead acid to come into contact with the perforated area for a predetermined period of time sufficient to prepare the formation for stimulation; removing the tool form the wellbore; and initiating the stimulation of the perforated area using a stimulation fluid. Also disclosed is a corrosion inhibiting composition for use with the acid composition.