Abstract: Lightweight proppant particles are disclosed. The lightweight proppant particle can include a proppant particle having an apparent specific gravity of at least about 1.5 g/cc, a coating of a hydrophobic material formed on an outer surface of the proppant particle, and a coating of an amphiphilic material formed on an outer surface of the coating of the hydrophobic material.

Abstract: The present disclosure relates to systems and methods for using aldehydes as a catalyst for oxidative breakers. An embodiment of the present disclosure is a method comprising: providing a treatment fluid that comprises: an aqueous base fluid, a polymeric gelling agent, a breaker that comprises an oxidative salt, and a catalyst that comprises an aldehyde; allowing the breaker to interact with the polymeric gelling agent; and allowing the viscosity of the treatment fluid to reduce.

Abstract: Lightweight proppant particles are disclosed. The lightweight proppant particle can include a proppant particle having an apparent specific gravity of at least about 1.5 g/cc, a coating of a hydrophobic material formed on an outer surface of the proppant particle, and a coating of an amphiphilic material formed on an outer surface of the coating of the hydrophobic material.

Abstract: Proppant particles coated with an arylolic resin/silicone resin copolymer, wherein the silicon resin contains D units and T units, are suitable for fracturing operations in geological formations and retain their deformability over time without becoming excessively brittle.

Abstract: Methods for treating a zone of a subterranean formation penetrated by a wellbore comprising: (A) forming a treatment fluid comprising: (i) an aqueous continuous phase; (ii) 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 the aqueous continuous phase; (iii) a second chemical having an amine group, wherein the second chemical is water soluble or dissolves with hydrolysis in the aqueous continuous phase; and (B) 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: The present invention includes the use of anhydride compositions, including alkyl and aryl anhydrides, for use as a demulsifier in resolving emulsions of water and oil. In particular, the anhydride composition can be used alone or in a blend with other demulsifiers. Suitable anhydrides suitable for the present invention include acetic and propionic, with acetic anhydride being preferred. The anhydride composition can be added directly to crude oil or other compositions to be resolved. As such, the demulsifier composition includes an anhydride, such as acetic anhydride, alone or in combination with other demulsifiers. The anhydride can be used in an amount ranging between trace and 100% by weight of the demulsifier composition.

Abstract: The present invention relates to methods for hydraulically fracturing a subterranean formation to improve the production rates and ultimate recovery by contacting unconsolidated resin-coated proppant particulates residing in a propped fracture with a reactive crosslinker in order to form a consolidated proppant pack. The present invention also relates to methods for use in water injection wells to consolidate the resin-coated proppant particulates in a gravel packed or frac packed region of a wellbore.

Abstract: A composition and method for hydraulically fracturing an oil or gas well to improve the production rates and ultimate recovery using a porous ceramic proppant infused with a chemical treatment agent is provided. The chemical treatment agent may be a tracer material that provides diagnostic information about the production performance of a hydraulic fracture stimulation by the use of distinguishable both water soluble and hydrocarbon soluble tracers. The tracer can be a biological marker, such as DNA. The porous ceramic proppant can be coated with a polymer which provides for controlled release of the chemical treatment agent into a fracture or well bore area over a period of time.

Abstract: A phenol-formaldehyde novolac resin having a low concentration of free phenol prepared by distilling residual phenol from a molten novolac resin and replacing at least a portion of the phenol with a solvent having a volatility equal to or less than phenol. Such modified novolac resins are suitable for the production of resin coated molding sands for shell molding and sand cores, as well as for the production of resin coated proppants for use in oil and gas recovery operations.

Abstract: A proppant comprises a particle and a polymeric coating disposed about the particle. The polymeric coating comprises the reaction product of a novolac polyol, an isocyanate, and an azole. The novolac polyol has a number average molecular weight of from about 200 to about 1000 g/mol. A method of forming the proppant comprises the steps of providing the particle, providing the novolac polyol, providing the isocyanate, and providing the azole. The method also includes the steps of combining the novolac polyol, the isocyanate, and the azole to react and form the polymeric coating and coating the particle with the polymeric coating to form the proppant.

Abstract: This invention relates to a resin preparable by reaction of a phenol/formaldehyde novolak with tetraethyl orthosilicate in a mass ratio above 28:1, wherein the phenol of the phenol/formaldehyde novolak is substituted or unsubstituted hydroxybenzene or a mixture of two or more such phenols, and to a particulate material coated with said resin. Said particles can be used e.g. in the shell molding process for the production of shell molds and shell cores; and as proppants for use in the hydraulic fracturing process.

Abstract: The present invention relates to a process for the production of coated proppants, proppants obtainable by such a process, uses thereof and processes using the proppants.

Abstract: The invention is directed to stable crosslinked water-soluble swellable polymers, methods for making same, and their various uses in the hygiene and medical arts, gel electrophoresis, packaging, agriculture, the cable industry, information technology, in the food industry, papermaking, use as flocculation aids, and the like. More particularly, the invention relates to a composition comprising expandable polymeric microparticles having labile crosslinkers and stable crosslinkers, said microparticle mixed with a fluid and an unreacted tertiary crosslinker that is capable of further crosslinking the microparticle on degradation of the labile crosslinker so as to form a stable gel.

Abstract: Consolidation fluids comprising: an aqueous base fluid comprising a hardening agent; an emulsified resin having an aqueous external phase and an organic internal phase; a silane coupling agent; and a surfactant. The consolidation fluid itself may be emulsified and further comprise an emulsifying agent. The consolidation fluid may also be foamed in some cases.

Abstract: The present invention relates to methods of cementing, for example, an oil or gas well. The method may involve pumping a suspension of a filler mixture and at least about 5 weight percent of a thermosetting resin based on the total weight of resin and filler mixture. Advantages may include superior properties and reliability as compared to conventional cementing operations often involving Portland cement.

Abstract: A meta crosslinked polar benzyl polymer is made by combining a transition metal crosslinker, or one or more source compounds capable of reacting to form such a transition metal crosslinker, with a polar benzyl polymer which has been activated for meta crosslinking

Abstract: Methods including providing a downhole tool or a component thereof comprising a plasticized polymer composition that comprises a polymer and a water-soluble plasticizer, wherein the plasticized polymer composition has a first deflection test value; exposing the downhole tool or the component thereof to an aqueous-based medium; allowing the water-soluble plasticizer to leach out of the downhole tool or the component thereof, wherein the plasticized polymer composition has a second deflection test value after exposure to the aqueous-based medium, and wherein the second deflection test value is less than about 10% of the first deflection test value; and placing the downhole tool or the component thereof in a subterranean formation.

Abstract: A phenol-formaldehyde novolac resin having a low concentration of free phenol prepared by distilling residual phenol from a molten novolac resin and replacing at least a portion of the phenol with a solvent having a volatility equal to or less than phenol. Such modified novolac resins are suitable for the production of resin coated molding sands for shell molding and sand cores, as well as for the production of resin coated proppants for use in oil and gas recovery operations.

Abstract: A subterranean treatment fluid comprising a degradable gemini surfactant composition described by the following formula: A and A? are spacers that may be a hydrophobic group or a hydrophilic group. B is an ion and may contain a quaternary nitrogen, a sulfonate, or a phosphate. A, A?, B, B?, C, C, E and E? may be an alkyl, an aryl, a sugar, an ester, an ether, and any combination thereof. D and D? may be an aryl, a sugar, an ester, an ether, and any combination thereof. In some cases, A?, D?, and E? may be optional.

Abstract: The present invention relates to a process for binding non-consolidated oxidic inorganic materials with curable formulations which comprise etherified amino resins, and to cured compositions obtainable by the process. A preferred embodiment of the invention comprises a process for stabilizing underground formations composed of oxidic inorganic materials, wherein the curable composition is injected into the underground formation and cured at the temperatures which exist in the formation.

Abstract: Consolidation fluids comprising: an aqueous base fluid comprising a hardening agent; an emulsified resin having an aqueous external phase and an organic internal phase; a silane coupling agent; and a surfactant. The consolidation fluid itself may be emulsified and further comprise an emulsifying agent. The consolidation fluid may also be foamed in some cases.

Abstract: Disclosed herein is a method comprising disposing in a formation fracture, a proppant and/or a fracturing fluid that comprises a radiation susceptible material that comprises indium and/or vanadium; irradiating the radiation susceptible material with neutrons; measuring gamma-radiation emitted from the radiation susceptible material in a single pass; wherein the single pass does not involve measuring of background radiation from previous or subsequent logging passes; and determining formation fracture height from the measured gamma-radiation.

Abstract: The present invention provides a process for the treatment of crude oil or aged crude oil residue comprising the steps of (a) contacting the oil or residue with a phenol resin and with a diluent, to provide a diluted phenol resin treated oil or residue; and (b) optionally removing solid material from the diluted phenol resin treated oil or residue.

Abstract: Methods are provided that include a method comprising: providing an emulsified treatment fluid comprising an oleaginous phase, an aqueous phase, a consolidating agent, and an emulsifying agent that comprises at least one convertible surfactant described by a one of the disclosed formulae, and placing the subterranean treatment fluid in a subterranean formation.

Abstract: Provided according to embodiments of the invention are resin coated particulates for use in oil and gas subterranean extractions. The resin coated particulates comprise a particulate substrate and a resin coating. The resin coating comprises a particulate substrate and a resin coating including epoxy-functional compounds and an aqueous dispersion of an amine functional microgel wherein the amine functional microgel is formed by reacting a chemical excess of a polyfunctional epoxide compound with an amine salt to form a polyfunctional epoxide amine salt reaction intermediate product, and condensing at least some of the unreacted epoxide groups of the polyfunctional epoxide amine salt reaction intermediate product with a polyamine. Methods of treating a subterranean fracture are also provided.

Abstract: Wellbore servicing fluids and methods of using the same to service a wellbore in a subterranean formation are provided. A filter cake in the wellbore is contacted with the gravel packing fluid, which comprises an oil-soluble additive capable of removing the filter cake. The additive undergoes hydrolysis to produce an acid upon contacting water provided from, for example, water in the wellbore servicing fluid, connate water in the subterranean formation, water in the filter cake, water produced by the subterranean formation, water pumped into the wellbore, or combinations thereof. The acid dissolves particulates in the filter cake in situ. In an embodiment in which the wellbore servicing fluid serves as a gravel packing fluid, the fluid also deposits gravel along the face of the subterranean formation, forming a barrier against the migration of sand from the formation and into the wellbore.

Abstract: Methods and compositions are provided that include degradable gemini surfactants including degradable gemini surfactants. Methods of use include subterranean operations, especially those involving the placement of resin systems, formation of emulsions (e.g., emulsified acids, emulsified fracturing fluids, drilling fluids, etc.), and in the formation of surfactant gelled fluids. Such treatments include, but are not limited to, drilling, stimulation treatments (e.g., fracturing treatments, acidizing treatments), and completion operations (e.g., sand control treatments like gravel packing).

Abstract: Disclosed herein is a method comprising disposing in a formation fracture, a proppant and/or a fracturing fluid that comprises a radiation susceptible material that comprises indium and/or vanadium; irradiating the radiation susceptible material with neutrons; measuring gamma-radiation emitted from the radiation susceptible material in a single pass; wherein the single pass does not involve measuring of background radiation from previous or subsequent logging passes; and determining formation fracture height from the measured gamma-radiation.

Abstract: Well treating composites are composed of an organic lightweight material and a weight modifying agent. The organic lightweight material preferably forms the continuous phase and the weight modifying agent forms the discontinuous phase. The apparent specific gravity (ASG) of the organic lightweight material is less than the ASG of the well treating composite. The composite of the invention is particularly useful in hydraulic fracturing fluids as lightweight proppants as well as in sand control methods, such as gravel packing and frac packing A subterranean formation may be treated by injecting the well treating composite into the formation in order to increase fracture conductivity, reduce the generation of fines, reduced unwanted water production and/or reduce particulate production.

Abstract: A method of treating a formation that includes emplacing an oxidizing breaker fluid into a region of the formation occupied by a gel; and allowing sufficient time for the oxidizing breaker fluid to degrade the gel is disclosed.

Abstract: Methods for servicing well bores with hardenable resin compositions are provided. In one embodiment, a method of servicing a well bore includes providing a hydrophobic well bore servicing composition comprising a liquid hardenable resin, a hardening agent, and a weighting material selected to impart a desired first density to the well bore servicing composition; introducing the well bore servicing composition into a well bore comprising a well bore fluid having a second density; allowing the well bore servicing composition to migrate through the well bore fluid to a desired location in the well bore based at least in part upon a difference between the first and second densities; and allowing the liquid hardenable resin to at least partially harden to form a well bore plug at the desired location in the well bore.

Abstract: Methods for servicing well bores with hardenable resin compositions are provided. In one embodiment, a method of servicing a well bore includes providing a hydrophobic well bore servicing composition comprising a liquid hardenable resin, a hardening agent, and a weighting material selected to impart a desired first density to the well bore servicing composition; introducing the well bore servicing composition into a well bore comprising a well bore fluid having a second density; allowing the well bore servicing composition to migrate through the well bore fluid to a desired location in the well bore based at least in part upon a difference between the first and second densities; and allowing the liquid hardenable resin to at least partially harden to form a well bore plug at the desired location in the well bore.

Abstract: A coated proppant comprising a proppant particulate substrate and a coating layer on the substrate. The coating layer is formed from a composition comprising a resin, a curing agent, an adhesion promoter, and a toughening agent.

Abstract: Methods and compositions for stabilizing portions of a subterranean formation that comprise unconsolidated particulates are provided. In one embodiment, a method of treating a subterranean formation includes introducing a pre-flush fluid into a subterranean formation comprising unconsolidated particulates; introducing a foamed consolidation fluid comprising an aqueous base fluid, an emulsified resin, a hardening agent, a silane coupling agent, and a surfactant into the subterranean formation subsequent to the pre-flush fluid; wherein the emulsified resin is emulsified prior to being introduced into the aqueous base fluid; and allowing the resin to cure to at least partially consolidate the unconsolidated particulates.

Abstract: Disclosed herein are free flowing coated particles and low temperature methods of making same. Each particle has a curable coating disposed upon a substrate. The substrate is a particulate substrate including an inorganic material, a particulate substrate including an organic material, a composite substantially homogeneous formed particle including a first portion of an at least partly cured binder and filler particles, or a hybrid particle having an inorganic particle as a core and a composite coating including at least partially cured resin and filler. The curable coating includes a continuous phase including a curable liquid resin and reactive powder particles embedded or adhered to the continuous phase. The reactive powder particles typically include one or more of a resole phenolic-formaldehyde resin, a novolak phenolic-formaldehyde resin, a polyester resin, an acrylic polymer resin, a urethane resin or an epoxy resin.

Abstract: The invention provides a method for treating a subterranean formation penetrated by a wellbore. The method comprises the steps of: (a) introducing a composition through the wellbore into the subterranean formation, wherein the composition comprises: (i) a solvent consisting essentially of an aqueous dissolvable solvent comprising any solvent that is at least 25% by weight soluble in water, wherein the solvent is from about 90% to about 99.9% by weight of the composition; and (ii) a curable resin, wherein the curable resin is from about 0.01% to about 10% by weight of the composition; wherein the curable resin and the solvent are mutually selected such that, for the ratio of the curable resin to the solvent, the curable resin is soluble in the solvent; and (b) installing a mechanical sand control device into the wellbore either before or after introducing the composition into the wellbore.

Abstract: A method for “tagging” proppants so that they can be tracked and monitored in a downhole environment, based on the use of composite proppant compositions comprising a particulate substrate coated by a material whose electromagnetic properties change at a detectable level under a mechanical stress such as the closure stress of a fracture. In another aspect, the invention relates to composite proppant compositions comprising coatings whose electromagnetic properties change under a mechanical stress such as the closure stress of a fracture. The substantially spherical composite proppants may comprise a thermoset nanocomposite particulate substrate where the matrix material comprises a terpolymer of styrene, ethylvinylbenzene and divinylbenzene, and carbon black particles possessing a length that is less than 0.

Abstract: Sealant compositions and methods of using the same to isolate a subterranean zone are provided. The compositions include partially polymerized furfuryl alcohol/aldehyde, a coupling agent, a diluent, a curing agent, a ductility imparting agent, and a filler for increasing the compressive strengths of the sealant compositions. Methods of isolating a subterranean zone include pumping the foregoing sealant composition into a well bore down through a conduit and up through an annulus disposed between the conduit and the walls of the well bore. The sealant composition exhibits a sufficiently long cure time such that it does not harden until it reaches the annulus. Thus, the sealant composition effectively attaches the conduit to the walls of the well bore. The sealant composition is substantially resistant to degradation by waste chemicals disposed of in the well bore.

Abstract: Composites containing a hydrocarbon-soluble well treatment agent may be supplied to a well using a porous particulate. Such well treatment agents may for example inhibit the formation of paraffins, salts, gas hydrates, asphaltenes and/or other deleterious processes such as emulsification (both water-in-oil and oil-in-water). Further, other well treatment agents include foaming agents, oxygen scavengers, biocides and surfactants as well as other agents wherein slow release into the production well is desired.

Abstract: The present invention discloses a mixed demulsifier of ASP flooding production liquid. The demulsifier consists of a functional demulsifier from 70 to 30% by mass and a mixed solvent from 30 to 70% by mass based on the mass of the demulsifier; the functional demulsifier is formed by mixing a polyethylidene polyamine polyoxypropylene polyoxyethylene ether from 35 to 70% by mass and a propanediol polyoxypropylene polyoxyethylene ether from 30 to 65% by mass based on the mass of the functional demulsifier; the mixed solvent comprises one or more of xylene, ethylbenzene, mixed benzene, solvent oil, methanol and isopropanol, or a mixed solution thereof with water. The demulsifier of the present invention has the advantages of high dehydration ratio, quick dehydration speed and flush oil-water interface over the prior art.

Abstract: The present invention relates to methods for making proppants on-the-fly during subterranean treatment operations. Some embodiments of the present invention provide methods of preparing proppant on-the-fly comprising providing discrete amounts of a resin mixture that comprises a resinous material and a filler material; placing the discrete amounts of resin mixture into a well bore comprising a treatment fluid; and, allowing the discrete amounts of the resin mixture to substantially cure and form proppant particles while inside the treatment fluid. Other embodiments of the present invention provide methods of fracturing a portion of a subterranean formation using proppant prepared on-the-fly.

Abstract: Disclosed are paraffin inhibitors prepared by admixing a polymer having the characteristic of inhibiting paraffin crystalline growth in formation fluid from oil and gas wells with a first solvent selected from the weak to moderate wax solvents and a second solvent selected from the strong wax solvents. Exemplary weak to moderate wax solvents include benzene, toluene, xylene, ethyl benzene, propyl benzene, trimethyl benzene and mixtures thereof. Exemplary strong wax solvents include cyclopentane, cyclohexane, carbon disulfide, decalin and mixtures thereof. The solvent system disclosed has desirably better solubility with the polymers, even at reduced temperatures, than either solvent alone. It is emphasized that this abstract is provided to comply with the rules requiring an abstract which will allow a searcher or other reader to quickly ascertain the subject matter of the technical disclosure. It is submitted with the understanding that it will be used to interpret or limit the scope or meaning of the claims.

Abstract: An aqueous fluid composition useful for the recovery of hydrocarbons from a subterranean formation, including a mixture of water, a water soluble polymer, an inorganic salt and at least one zwitterionic surfactant and methods of using same.

Abstract: The present invention relates to improved methods for drilling well bores penetrating producing zones while controlling formation particulates.

Abstract: Plastic beads, including polyamides and polystyrene beads crosslinked with divinylbenzene, having a curable resin coating are highly useful for sand control and/or hydraulic fracturing of subterranean. The curable resin coated plastic beads preferably have an apparent specific gravity less than about 1.5.

Abstract: Methods and compositions relating to delayed tackifying compositions that comprise an aqueous tackifying agent and a delayed acid-releasing activator that may be used to stabilize particulates and reduce particulate migration within a subterranean formation.

Abstract: The present invention concerns a water-based drilling mud for utilization in the drilling of oil wells comprising an aqueous phase wherein the aqueous phase contains an oil soluble polymer in the form of a gel as a fluid loss reducer.

Abstract: A wellbore servicing comprising a calcium aluminate cement and at least one gelation inhibitor wherein the calcium aluminate cement comprises less than about 50 wt. % alumina, greater than about 2 wt. % iron oxide, or both. A wellbore servicing composition comprising calcium aluminate cement and a gelation inhibitor, wherein the gelation inhibitor comprises a copolymer comprising one or more sulfonated aromatic monomers and one or more acrylate monomers. A wellbore servicing composition comprising calcium aluminate cement and a gelation inhibitor, wherein the gelation inhibitor comprises a copolymer comprising alkylbenzene sulfonic acid, at least one methallyl sulfonic acid monomer; at least one copolymerizable nonionic monomer, and at least one copolymerizable olefinically unsaturated carboxylic acid monomer.

Abstract: Hollow non-porous metallic spheres may be used in treatment of subterranean formations, including hydraulic fracturing and sand control methods, such as gravel packing. The spheres typically having a diameter ranging from about 4 mesh to about 100 mesh. When employed in deep water environments having high closure stresses, the spheres have a thicker wall and are characterized by the higher ASG, typically between 2.5 to about 4.0. The ASG of the spheres, when less harsh environments are encountered, is generally ultra lightweight (ULW) with an ASG less than or equal to 2.0. Fracture conductivity may be increased by the placement of the hollow non-porous metallic spheres as a partial monolayer.

Abstract: Novel uses of reactive surfactants in treating subterranean formations and/or proppant particulates are provided. In one embodiment, the present invention provides a method comprising: providing a treatment fluid that comprises a base fluid and a reactive surfactant; introducing the treatment fluid into a subterranean formation; and allowing the reactive surfactant to interact with a surface in the subterranean formation.