Abstract: Of the many methods provided herein, one method of reducing the viscosity of a viscosified treatment fluid includes: providing a clean-up composition comprising a carboxylic acid; providing a chlorite-based breaker system; providing a viscosified treatment fluid; placing the viscosified treatment fluid in a subterranean formation via a well bore penetrating the subterranean formation; contacting the viscosified treatment fluid with the clean-up composition; contacting the viscosified treatment fluid with the chlorite-based breaker; and allowing the viscosity of the viscosified treatment fluid to reduce. Also provided herein are methods that include a method of reducing polymeric residue from a subterranean formation that includes: placing a clean-up composition and a chlorite-based breaker system in a subterranean formation in contact with an amount of polymeric residue; and allowing the amount of polymeric residue present in the formation to be reduced.

Abstract: Use of two different methods, either each by itself or in combination, to enhance the stiffness, strength, maximum possible use temperature, and environmental resistance of thermoset polymer particles is disclosed. One method is the application of post-polymerization process steps (and especially heat treatment) to advance the curing reaction and to thus obtain a more densely crosslinked polymer network. The other method is the incorporation of nanofillers, resulting in a heterogeneous “nanocomposite” morphology. Nanofiller incorporation and post-polymerization heat treatment can also be combined to obtain the benefits of both methods simultaneously. The present invention relates to the development of thermoset nanocomposite particles.

Abstract: A method for fracture stimulation of a subterranean formation includes providing a thermoset polymer nanocomposite particle precursor composition comprising a polymer precursor mixture, dispersed within a liquid medium, containing at least one of an initiator; at least one of a monomer, an oligomer or combinations thereof, said monomer and oligomer having three or more reactive functionalities capable of creating crosslinks between polymer chains; at least one of an impact modifier; and nanofiller particles substantially dispersed within the liquid medium; subjecting the nanocomposite particle precursor composition to suspension polymerizing conditions; subjecting the resulting nanocomposite particles to heat treatment; forming a slurry comprising a fluid and a proppant that includes the heat-treated nanocomposite particles; injecting the slurry into a wellbore; and emplacing the proppant within a fracture network in the formation.

Abstract: Fluid systems may contain elements to provide changes in bulk fluid density in response to various environmental conditions. One environmental driver to the variable density is pressure; other environmental drivers include, but are not limited to, temperature or changes in chemistry. The variable density of the fluid is beneficial for controlling sub-surface pressures within desirable pore pressure and fracture gradient envelopes. The variability of fluid density permits construction and operation of a wellbore with much longer hole sections than when using conventional single gradient fluids.

Abstract: Use of two different methods, either each by itself or in combination, to enhance the stiffness, strength, maximum possible use temperature, and environmental resistance of such particles is disclosed. One method is the application of post-polymerization process steps (and especially heat treatment) to advance the curing reaction and to thus obtain a more densely crosslinked polymer network. The other method is the incorporation of nanofillers, resulting in a heterogeneous “nanocomposite” morphology. Nanofiller incorporation and post-polymerization heat treatment can also be combined to obtain the benefits of both methods simultaneously. The present invention relates to the development of thermoset nanocomposite particles.

Abstract: Subterranean treatment fluids comprising: an aqueous base fluid and a reaction product of a gelling agent comprising a copolymer or salt thereof comprising N-[tris(hydroxymethyl)methyl]acrylamide, 2-acrylamido-2-methylpropanesulfonic acid or a salt thereof, acrylamide; and a crosslinking agent. Such treatment fluids are particularly well-suited for high temperature applications. In particular, they are suited for subterranean temperatures up to about 400° F.

Abstract: A bimodal bioabsorbable polymer composition. The composition includes a first amount of a bioabsorbable polymer polymerized so as to have a first molecular weight distribution; a second amount of said bioabsorbable polymer polymerized so as to have a second molecular weight distribution having a weight average molecular weight between about 10,000 to about 50,000 Daltons, the weight average molecular weight ratio of said first molecular weight distribution to said second molecular weight distribution is at least about two to one; wherein a substantially homogeneous blend of said first and second amounts of said bioabsorbable polymer is formed in a ratio of between about 50/50 to about 95/5 weight/weight percent. Also disclosed are a medical device, a method of making a medical device and a method of melt blowing a semi-crystalline polymer blend.

Abstract: Additives useful in attenuating the crosslinking time of sparingly soluble borate minerals and the use of those additives in oil well fracturing fluids and methods are described.

Abstract: Scale inhibiting particulates formed from a mixture of fly ash and a phosphonic acid curing agent; wherein the fly ash is cured into a solid material by the contact with the phosphonic acid curing agent. The mixture may also contain a multivalent ion and the particulates may be coated with a coating material in an amount from about 0.1% to about 40% coating material by weight of the scale inhibiting particulate to delay the release of the scale inhibitor.

Abstract: A low-density ceramic proppant is formed from a light aggregate of a natural mineral and a ceramic binding material in the form of a proppant granule. The light aggregate expands in volume when burnt so that the density of the aggregate is changed. A method of preparing a proppant material is carried out by pre-crushing and pre-mixing of raw components. This is followed by their granulation into proppant granules, drying and screening of the granules to a selected size. The raw components include at least a ceramic binding material and a light aggregate of a natural mineral that, when burnt, expands in volume so that the specific volume of the aggregate is changed. The burning of the light aggregate may be accomplished before or after the aggregate is mixed with the binding material.

Abstract: An additive composition including a synergistic combination of a hectorite organoclay composition and an attapulgite organoclay composition. The hectorite organoclay composition includes (i) a first organic cation provided by an alkoxylated quaternary ammonium salt; and ii) a second organic cation wherein such second organic cation is not provided by an alkoxylated quaternary ammonium salt. The attapulgite organoclay composition includes (iii) a third organic cation provided by an alkoxylated quaternary ammonium salt; and (iv) a fourth organic cation wherein such third organic cation is not provided by an alkoxylated quaternary ammonium salt.

Abstract: The process for making amphoteric surfactants derived from ether amine s is described. The ether amines may be derived from natural products such as animal, marine or vegetable oils or from petroleum derived raw materials. The application of these amphoteric surfactants to the recovery of residual oil by Enhanced Oil Recovery methods is disclosed.

Abstract: A composition of the formulae MZAORSnR1F1mOAZ1M1, wherein O and S have their normal meaning of oxygen and sulfur, n is at least 2 and not more than 8, F1 is of the formula —OAORSnR1—, m is at least 1, Z and Z1 are the same or different and are oxy or amino, M and M1 are the same or different and are hydrogen or an organic substituent, R and R1 are the same or different and are organic divalent radicals, each having from 2 to 20 carbon atoms, and A is the residue of a dicarboxylic acid of from 2 to 40 carbon atoms.

Abstract: A treatment fluid composition for treating a subterranean formation penetrated by a wellbore is formed from an aqueous fluid, a hydratable polymer and a water-soluble, non-symmetrical, inorganic peroxide breaking agent, which is capable of undergoing heterolytical cleavage. A method of treating a subterranean formation penetrated by a wellbore may also be performed by forming a treatment fluid from an aqueous hydrated polymer solution. This is combined with a water-soluble, non-symmetrical, heterolytically cleavable inorganic peroxide breaking agent. The treating fluid is introduced into the formation. An optional crosslinking agent capable of crosslinking the polymer may also be included.

Abstract: The invention relates to corrosion inhibitor compositions comprising products of a reaction between aldehydes and amides for use in subterranean applications and methods related thereto. In general, the methods for inhibiting corrosion comprise providing a corrosive environment and adding a composition comprising a corrosion inhibitor to the corrosive environment. The corrosion inhibitor comprises a product of a reaction between at least one aldehyde and at least one amide that is not formamide or a formamide derivative.

Abstract: A method for fracture stimulation of a subterranean formation having a wellbore. The method comprise a series of steps. A slurry is injected into the wellbore at sufficiently high rates and pressures such that the formation fails and fractures to accept the slurry. The slurry comprises a fluid and a proppant, wherein said proppant comprises a styrene-ethylvinylbenzene-divinylbenzene terpolymer composition having a substantially cured polymer network, wherein said composition lacks rigid fillers or nanofillers. The proppant is emplaced within the fracture network in a packed mass or a partial monolayer of the proppant within the fracture, wherein the packed mass or partial monolayer props open the fracture; thereby allowing produced gases, fluids, or mixtures thereof, to flow towards the wellbore.

Abstract: An aqueous or oil-based mixture containing a non-toxic, low pH, antimicrobial, acidic composition having a pH between approximately 0.5 and approximately 3.5 with and without a proppant is used as a subterranean well stimulation additive. Without a proppant, the LpHAC stimulation additive is used for acidization. In another embodiment, with a proppant, the LpHAC stimulation fluid is used in hydraulic fracturing. As a well stimulation fluid, it involves the injection of specially engineered fluids and other materials into the well bore at rates that actually cause the cracking or fracturing of the reservoir formation to create fissures or cracks in the formation to increase fluid flow of underground resources from the reservoir into the well bore.

Abstract: A method of secondary oil recovery is disclosed wherein from 0.1 to 100 000 ppm of a medium soluble aminoalkylene phosphonic acid amine salt are used wherein both the aminoalkylene phosphonic acid moiety and the amine moiety are selected from a specifically defined class of compounds. The substantially medium soluble aminoalkylene amine phosphonates exhibit a significantly improved compatibility with the recovery medium and thus can propagate fairly freely into the medium and consequently cover a largely extended rock surface before being subject to precipitation in the form of a medium insoluble scale inhibitor. The amine compound is represented by combinations of structurally different compounds.

Abstract: Using a complex emulsion for treating a subterranean formation, such as to dissolve minerals therein (e.g. carbonates, scales, and/or filter cake) to improve permeability, substantially improves post treatment fluid clean-up for improved hydrocarbon production. The complex emulsion is made by mixing an acid aqueous phase with an oil external microemulsion to give an initial product, where the acid aqueous phase is an external phase and the microemulsion is an internal phase. Then the initial product is mixed with a second oil (e.g. xylene, diesel, toluene, kerosene, other aromatics, refined hydrocarbons and the like) containing an emulsifier to make a complex emulsion.

Abstract: Fluid systems may contain elements to provide changes in bulk fluid density in response to various environmental conditions. One environmental driver to the variable density is pressure; other environmental drivers include, but are not limited to, temperature or changes in chemistry. The variable density of the fluid is beneficial for controlling sub-surface pressures within desirable pore pressure and fracture gradient envelopes. The variability of fluid density permits construction and operation of a wellbore with much longer hole sections than when using conventional single gradient fluids.