Abstract: Of the methods provided herein, is a method comprising: providing a treatment fluid comprising an aqueous base fluid, an inorganic oxidizer and an activator selected from the group consisting of N-acyl caprolactam based activators, substitutes benzoyl caprolactam based activators and mixtures thereof are provided; and preparing the treatment fluid for use in a down-hole operation, where the down-hole operation is either a gel breaking operation or a formation conditioning operation.

Abstract: Methods and systems for maintaining stability of contaminated drilling muds within a desirable range by chemical and/or physical treatment. In one aspect, a method includes injecting a drilling mud in a subterranean zone, the drilling mud including a quantity of a first drilling mud additive including a volcanic ash, determining a presence of a gas associated to a process of the subterranean zone, and neutralizing the gas by injecting a quantity of a second drilling mud additive through the subterranean zone, the second drilling mud additive including a gas neutralizer.

Abstract: A method of installing a downhole device comprises introducing a downhole device into a wellbore, the downhole device comprising a substrate and a shape memory polymer in a deformed state disposed on the substrate; combining a modified activation material in the form of a powder, a hydrogel, an xerogel, or a combination comprising at least one of the foregoing with a carrier to provide an activation fluid; introducing the activation fluid into the wellbore; releasing an activation agent in a liquid form from the modified activation material; and contacting the shape memory polymer in the deformed state with the released activation agent in an amount effective to deploy the shape memory polymer.

Abstract: Embodiments of the invention provide methods and composition for stimulating a hydrocarbon-bearing, heavy oil containing formation, a deep oil reservoir, or a tight oil reservoir, whereby exothermic reactants are utilized to generate in-situ steam and nitrogen gas downhole in the formation or the reservoir as an enhanced oil recovery process. An oil well stimulation method is provided, which includes injecting, into the one of the formation and the reservoir, an aqueous composition including an ammonium containing compound and a nitrite containing compound. The method further includes injecting, into the one of the formation and the reservoir, an activator. The activator initiates a reaction between the ammonium containing compound and the nitrite containing compound, such that the reaction generates steam and nitrogen gas, increasing localized pressure and improving oil mobility, in the one of the formation and the reservoir, thereby enhancing oil recovery from the one of the formation and the reservoir.

Abstract: A method for recovering hydrocarbons in a carbonate reservoir by introducing a saline solution injection containing a saline soluble surfactant and a saline soluble polymer. The method provides for increased hydrocarbon recovery as compared to conventional waterflooding techniques.

Abstract: A fiber delivery system capable of providing cut fiber segments for use in treating an oil and/or gas well. The fiber delivery system can utilize bales of a continuous filamentary tow that are transported to the well site from a remote manufacturing location. At the well site, a multifilament strand can be pulled off the bale, opened, and cut to provide cut fiber segments. The cut fiber segments can be mixed with other well treatment components to create a well treatment medium that is introduced into the well as part of a drilling, stimulation, or cementing process.

Abstract: The present invention provides, a method of controlling scale formation in a hydrocarbon producing system, comprising; (i) injecting nanoparticles into said system to function as nuclei for scale growth; (if) allowing scale growth to occur on said nanoparticles to produce nanoparticles comprising scale; and. (in) optionally recovering said nanoparticles comprising scale.

Abstract: Included are methods and systems for drilling in a subterranean formation. A method comprises providing a drilling fluid comprising an aqueous base fluid and a betaine shale stabilizer; placing the drilling fluid into the subterranean formation; and drilling a wellbore in the subterranean formation. A drilling system comprises a drilling fluid comprising an aqueous base fluid and a betaine shale stabilizer; a drilling assembly; a drill string coupled to the drilling assembly; a pumping system fluidically coupled to the drill string, wherein the pumping system is capable of pumping the drilling fluid through the drill string.

Abstract: A method of enhanced oil recovery wherein: (a) a flooding composition is delivered into a subterranean reservoir; (b) the flooding composition includes a sulfur surfactant; and (c) the fluid produced from the subterranean reservoir can also be analyzed to determine if the surfactant is present in the fluid. The surfactant preferably includes a sulfonate moiety or other sulfur-containing moiety. The presence of the surfactant in the fluid produced from the subterranean reservoir is preferably determined by X-ray fluorescence spectroscopy, HPLC-AES, or HPLC-ICP.

Abstract: A method of extracting hydrocarbons from a subterranean formation comprises forming a suspension comprising reactive particles and a carrier fluid. The suspension is introduced into a subterranean formation containing a hydrocarbon material. At least a portion of the reactive particles are exothermically reacted with at least one other material within the subterranean formation to form a treated hydrocarbon material from the hydrocarbon material. The treated hydrocarbon material is extracted from the subterranean formation. An additional method of extracting hydrocarbons from a subterranean formation, and a method of treating a hydrocarbon material within a subterranean formation are also described.

Abstract: An aqueous fracturing fluid comprises an environmentally friendly flowback aid. The flowback aid includes an amine oxide having the formula (CH3)NO(R1)(R2), where R1 and R2 are independently selected from linear or branched alkyl groups having from 8 to 16 carbon atoms. Optionally, the fracturing fluid may further comprise an alcohol ethoxylate of the formula R3—(OC2H4)x—OH, wherein R3 is a linear or branched alkyl group having from 6 to 18 carbon atoms, and wherein x ranges from 3 to 25. One example of an amine oxide is didecylmethyl amine oxide, and one example of an alcohol ethoxylate is ethoxylated isodecylalcohol (also known as ethoxylated isodecanol). The fracturing fluid is introduced through a well bore into the subterranean formation and pressurized to fracture the subterranean formation. The fracturing fluid is then allowed to flow back into the well bore from the subterranean formation.

Abstract: A method of enhanced oil recovery wherein: (a) a flooding composition is delivered into a subterranean reservoir; (b) the flooding composition includes a sulfur surfactant; and (c) the fluid produced from the subterranean reservoir can also be analyzed to determine if the surfactant is present in the fluid. The surfactant preferably includes a sulfonate moiety or other sulfur-containing moiety. The presence of the surfactant in the fluid produced from the subterranean reservoir is preferably determined by X-ray fluorescence spectroscopy, HPLC-AES, or HPLC-ICP.

Abstract: The present invention discloses a phase change fracturing fluid system for phase change fracturing, including the following components in percentage by weight: 10%-40% of supramolecular construction unit, 0-40% of supramolecular function unit, 0.5%-2% of surfactant, 0-5% of inorganic salt, 0.5%-2% of oxidizing agent, 0-2% of cosolvent and the remaining of solvent. The supramolecular construction unit is melamine, triallyl isocyanurate, or a mixture thereof. The supramolecular function unit is vinyl acetate, acrylonitrile, or a mixture thereof. The solvent is methylbenzene, ethylbenzene, o-xylene, m-xylene or p-xylene. In the fracturing construction process, a conventional fracturing fluid is used for fracturing a formation first; the phase change fracturing fluid is then injected into the formation, or the phase change fracturing fluid and other fluids which cannot be subjected to phase change are injected into the formation together.

Abstract: A method for optimized matrix acidizing, including a method for determining fracture pressure of a formation as a function of bottom hole temperature. First and second cycles of a step up rate test may be performed on the formation to be acidized at first and second test temperatures, respectively. From the first and second cycles, a mathematical relationship for fracture pressure of the formation as a function of bottom hole temperature may be formulated and integrated into a fluid placement simulator. A design matrix acidizing treatment plan accounting for an effect of bottom hole temperature on fracture gradient may simulated, and matrix acidizing treatment thereafter performed according to the design plan, thereby resulting in more accurate matrix acidizing treatment and minimization of inefficient fluid placement by adherence to actual formation fracture pressure limits.

Abstract: A hybrid particle mix lost circulation material (LCM) is provided. The hybrid particle mix LCM includes date palm seed particles produced from date palm seeds and scrap tire particles produced from scrap tires. The LCM may include date palm seed particles in the range of about 50 wt % to about 80% and scrap tire particles in the range of about 50 wt % to about 20 wt %. Methods of lost circulation control and manufacture of a hybrid particle mix LCM are also provided.

Abstract: A hybrid particle mix lost circulation material (LCM) is provided. The hybrid particle mix LCM includes date palm seed particles produced from date palm seeds and scrap tire particles produced from scrap tires. The LCM may include date palm seed particles in the range of about 50 wt % to about 80% and scrap tire particles in the range of about 50 wt % to about 20 wt %. Methods of lost circulation control and manufacture of a hybrid particle mix LCM are also provided.

Abstract: Methods for treating a zone of a subterranean formation penetrated by a wellbore comprising: (A) introducing an acidizing fluid into the zone of the subterranean formation; (B) forming a treatment fluid comprising: (i) a first chemical having: (a) a single epoxy group; and (b) at least one alkoxy group on a silicon atom, wherein the first chemical is water soluble or dissolves with hydrolysis in an aqueous phase; and (ii) a second chemical having an amine group, wherein the second chemical is water soluble or dissolves with hydrolysis in an aqueous phase; and (C) introducing the treatment fluid through the wellbore into the zone of the subterranean formation. In various embodiments, the treatment fluid has a viscosity of less than 5 cP measured at a shear rate of 511 sec?1.

Abstract: Some embodiments herein described relate to method comprising: providing a portion of a subterranean formation comprising unconsolidated particulates; introducing a polymerizable aqueous consolidation composition into the portion of the subterranean formation so as to contact the unconsolidated particulates with the polymerizable aqueous consolidation composition, thereby creating coated, unconsolidated particulates; introducing a substantially solids-free, aqueous flush fluid into the portion of the subterranean formation so as to remove the polymerizable aqueous consolidation composition from interstitial spaces between the coated, unconsolidated particulates; introducing a water-soluble polymerization initiator composition into the portion of the subterranean formation so as to contact the coated, unconsolidated particulates; and consolidating the coated, unconsolidated particulates in the portion of the subterranean formation.

Abstract: Methods and compositions for the prevention of the formation, breakdown, and/or removal of gelled layers in an oil and/or gas well are provided. In some embodiments, the compositions and methods comprise a concentrate, as described in more detail herein, where the concentrate comprises two or more surfactants. In certain embodiments, the compositions and methods comprise an emulsion or a microemulsion. The emulsion or microemulsion may include a surfactant, optionally a solvent, and optionally a freezing point depression agent or other components.

Abstract: The present invention is related with a biotechnological process that increases the recovery and mobilization of oils present in carbonated and/or siliciclastic porous media by the action of tensoactive biomolecules from Serratia marcescens SmSA. The invention also increases the oil recovery in reservoirs. Serratia marcescens SmSA biomolecules display tensoactive and emulsifying properties that produce changes in the surface and interfacial tensions, enhanced the recovery and mobilization of oils. The Serratia marcescens SmSA tensoactive biomolecules of the present invention are stable at temperatures from 4 to 121° C., pH from 2 to 12, pressures from atmospheric to 1,706 psi, and NaCl content from 0 to 200 g/L (from 0 to 200,000 ppm). The Serratia marcescens SmSA tensoactive biomolecules reduce the surface tension up to 26 mN/m, the interfacial tension up to 1.8 mN/m with hexadecane, with emulsifying activity up to 71% with the same solvent and a critical micellar concentration (CMC) of 300 mg/L.