Abstract: In general, the current application relates to degradable composite and blend materials that have accelerated degradation in water in low temperature conditions, and their various industrial, medical and consumer product uses. In some embodiments, the degradable composite composition comprises a degradable polymer mixed with discrete particles of a filler that acts to accelerate the degradation of the degradable polymer. Such materials degrade in 60 C water in less than 30 days, <14 days, and even <7 days. Various materials are provided that can degrade equally fast at lower temperatures, such as 50 C, or even 40 C.

Abstract: A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising a resin material, a silane coupling agent, and an aqueous base fluid, placing the wellbore servicing fluid in the wellbore and/or subterranean formation, and allowing the wellbore servicing fluid to harden therein.

Abstract: An invert emulsion treatment fluid comprises: (A) an external phase, wherein the external phase comprises a hydrocarbon liquid; (B) an internal phase, wherein the internal phase comprises a hygroscopic liquid; (C) a suspending agent, wherein the suspending agent is a polymer, and wherein the polymer comprises urea linkages; and (D) a particulate, wherein the particulate has a density less than 3.5 g/cm3, wherein a test fluid consisting essentially of the external phase, the internal phase, the suspending agent, and the particulate, and in the same proportions as the treatment fluid, and after static aging for 2 months at a temperature of 200° F. (93.3° C.), has a 10 minute gel strength of at least 30 lb/100 ft2 (1,436 Pa) at a temperature of 120° F. (48.9° C.). A method of using the invert emulsion treatment fluid comprises: introducing the treatment fluid into a portion of a subterranean formation.

Abstract: A proppant for use in fracturing a subterranean formation is characterized by specific mean particle size, particle size standard deviation, and aspect ratio. The proppant is prepared from a thermoplastic composition that includes specific amounts of a polyamide and a poly(phenylene ether). The proppant is useful for propping a fracture in a subterranean formation.

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

Abstract: Biomimetic adhesive compositions can be used in various aspects of subterranean treatment operations. Methods for treating a subterranean formation can comprise: providing an adhesive composition that comprises a first polymer comprising a plurality of monomers that comprise a phenolic moiety, a biopolymer that is crosslinkable with the first polymer, a crosslinking agent, and an oxidizing agent; introducing the adhesive composition into a subterranean formation; and forming a coacervate-bound surface in the subterranean formation by crosslinking the first polymer.

Abstract: A method of treating a subterranean formation penetrated by a wellbore involves introducing an acid treatment fluid through the wellbore into the formation. The treatment fluid is formed from a zwitterionic viscoelastic surfactant, an acid in an amount to provide the treatment fluid with an initial pH of ?0 and a rheology enhancer. The treatment fluid has a high viscosity at the initial pH and a lower viscosity when the pH of the treatment fluid is raised to an intermediate pH of from greater than 0 to about 5.

Abstract: The present disclosure is directed to compositions and methods that may be used for enhanced oil recovery, for modifying the permeability of subterranean formations and for increasing the mobilization and/or recovery rate of hydrocarbon fluids present in the formations. The compositions may include, for example, expandable cross linked polymeric microparticles having an unexpanded volume average particle size diameter of from about 0.05 to about 5,000 microns and a cross linking agent content of from about 100 to about 200,000 ppm of hydrolytically labile silyl ester or silyl ether crosslinkers and from 0 to about 300 ppm of non-labile crosslinkers.

Abstract: The present invention relates to a liquefied polymer fracturing fluid thickener, which has evaluation indexes as: a density of 1.0-1.3 g/cm3; a gelling time less than or equal to 15 s; and a viscosity of its 1.0% solution greater than or equal to 30 mPa·s. The present invention also relates to a method for preparing said liquefied polymer fracturing fluid thickener.

Abstract: Reduction of the water permeability within a subterranean formation, particularly within a proppant pack or a gravel pack, can be achieved through the use of a relative permeability modifier (RPM) coated on a particulate material. Methods for reducing the water permeability include providing RPM-coated particulates that contain a RPM coating on the particulates, and placing a treatment fluid containing a base fluid and the RPM-coated particulates in at least a portion of a subterranean formation. The treatment fluid can also contain a companion polymer that serves to further reduce the water permeability compared to that achievable when using the RPM alone.

Abstract: A composition, treatment fluid and method using hydrolyzable fines. A treatment fluid, which may optionally include a high solids content fluid (HSCF) and/or an Apollonianistic solids mixture, includes a fluid loss control agent comprising a dispersion of hydrolyzable fines, optionally with one or more of a surfactant, plasticizer, dispersant, degradable particles, reactive particles and/or submicron particles selected from silicates, ?-alumina, MgO, ?-Fe2O3, TiO2, and combinations thereof.

Abstract: A method of treating an earth formation that includes introducing at least one blocked isocyanate in a liquid phase into the earthen formation; introducing at least one active hydrogen compound into the earthen formation; and contacting the blocked isocyante and the active hydrogen compound form an elastomeric gel is disclosed.

Abstract: Polylactide fibers are made from a blend of polylactides. One of the polylactides has a ratio of R-lactic and S-lactic units from 8:92 to 92:8. The second polylactide has a ratio of the R-lactic and S-lactic units of >97:3 or <3:97. The ratio of the R-lactic units to S-lactic units in the blend is from 7:93 to 25:75 or from 75:25 to 93:7. The polylactide fiber contains at least 5 Joules of polylactide crystallites per gram of polylactide resin in the fiber.

Abstract: This invention relates to the development of nanoparticles, which can be used as tracers, in order to track the movement of fluids injected into an oil reservoir. The injected fluids diffuse through a solid geological medium which constitutes the oil reservoir, thus making it possible to study this latter by following the path of the injected fluids. The objective is in particular to monitor the flows between the injection well(s) and the production well(s) and/or to evaluate the volumes of oil in reserve and water in the reservoir and ultimately to optimize oil exploration and exploitation.

Abstract: There is provided synthetic proppants, and in particular polysilocarb derived ceramic proppants. There is further provided hydraulic fracturing treatments utilizing these proppants, and methods of enhance hydrocarbon recovery.

Abstract: Controlling the formation of crystalline hydrates in various fluid systems, most notably, gas and oil transmission pipeline systems by contacting the systems with certain polymers or polymers associated with solid particles. The polymers useful are chelating polymers capable of interacting with charged gaseous molecules such as carbon dioxide, by removing the carbon dioxide, or more practically by scavenging for the carbon dioxide, to prevent the methane or ethane hydrate structures from forming since they require carbon dioxide to stabilize their structures.

Abstract: A drag-reducing additive includes 40-85% by weight of a polymer emulsion that includes a polymer, a first surfactant, and a first solvent; 10-35% by weight of a second surfactant with an HLB greater than 8; and 5-30% by weight of a second solvent. In a preferred embodiment, the second solvent includes a terpene. In another preferred embodiment, the polymer is a copolymer that includes acrylamide and acrylic acid.

Abstract: Proppants for use in fractured or gravel packed/frac packed oil and gas wells are provided with a contaminant removal component to remove one or more of the contaminants found in subterranean water/hydrocarbon from a production well. The water/hydrocarbon cleaning proppant solids may be used as discrete particles in a proppant formulation, as a coating on proppant solids in pores of a porous proppant solid or as part of the proppant's internal structure. The contaminant removal component removes contaminants, especially dissolved contaminants, in the subterranean water or hydrocarbon before the water/hydrocarbon leaves the well. For those contaminant removal components that can be regenerated, such as ion exchange resins, a measured quantity of an acidic regeneration solution can be injected into the fractured stratum for regeneration and recovered when the well resumes production.

Abstract: Foamable epoxy-based zonal isolation sealing compositions include epoxy resin and a blowing agent and methods for isolating zones in borehole of oil and gas wells using the compositions, where the foam nature of the cured seals provide sufficient compressibility and resiliency to be used with expandable tubing without substantial loss in sealant integrity and in squeeze operations.

Abstract: In one aspect, embodiments disclosed herein relate to a wellbore strengthening composition including at least one polymer capable of polymerizing through a free radical polymerization reaction from the group of epoxy acrylates, modified epoxy acrylates, epoxy precursors, modified epoxy vinyl esters, unsaturated polyesters, urethane(meth)acrylates, polyester acrylates, epoxy vinyl ester resins having the wherein R and R1-R5 may be CH3— or H and R6-R21 may be H or Br, and polymer combinations thereof; and at least one initiator, wherein the resin is present in the amount from about 10 to about 90 weight percent.

Abstract: The invention provides a method for increasing the retention of a scale inhibitor within a hydrocarbon producing system, including the steps of: (i) pre-flushing said system with a liquid; (ii) treating said system with a scale inhibitor; and (iii) over-flushing said system with a composition comprising an ionic polymer and a liquid carrier, wherein the concentration of said ionic polymer in said composition is 5 to 50% wt.

Abstract: Methods of creating degradable particulates in a subterranean environment. The methods provide a degradable material supercritical fluid mixture that comprises degradable material into a wellbore penetrating a subterranean formation and provide an orifice between the wellbore and the subterranean formation wherein the pressure in the subterranean formation is less than the pressure in the wellbore. The degradable material supercritical fluid is then fed through the orifice into the subterranean formation such that the degradable material supercritical fluid mixture expands through an orifice into the lower subterranean formation and particulates are formed.

Abstract: A self-adaptive cement formulation includes cement, water and asphaltite-mineral particles. The set cement demonstrates self-healing properties when exposed to methane, and is particularly suited for well-cementing applications. After placement and curing, the self-healing properties help maintain zonal isolation should bonding be disrupted between the set cement and the formation or a casing string, should cracks or defects appear in the set-cement matrix, or both.

Abstract: This invention discloses articles, in the form of particles to small granules to macro sized objects, capable of the controlled release of active ingredients (AI) from a mixture as a solid solution, a matrix or an encapsulated system containing AI and one or more of polymers, additives and/or carriers. The invention also covers additional surface coatings on those articles to further reduce the rate of release of AI. Finally, methods for producing these articles and treating the oil field well and other segments of the oil industry, for example piping, storage tank, and refinery locations, are introduced. The claimed articles can be used as is or mixed with other oil filed components or system, for example proppant fluid, in oil field applications.

Abstract: The present disclosure is directed degradable polymers. The polymers are solid when maintained under substantially dry conditions at a temperature of up to about 90 degrees C. When contacted with water at a temperature of up to about 90 degrees C., however, the polymers initially remain solid for a period of up to about 6 to about 24 hours, then depolymerize to provide a liquid having a viscosity of from about 1 to about 200,000 centipoise after a period of time from about 8 hours to about 3 days and then further depolymerizes to water-soluble components after a period of time at least about 3 days. Also disclosed are sand screen coatings made with the polymers and hydraulic and acid fracturing methods using the polymers.

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: Proppants for hydraulic fracturing of oil and gas wells are coated with a polyurea-type coating. In a preferred embodiment, the polyurea-type coating is formed by contacting a polymeric isocyanate with an amount of water and a blowing catalyst at a rate and quantity sufficient to generate a reactive amine in situ on the outer surface of the proppant which thereby reacts with unconverted polymeric isocyanate to form a thin polyurea-type surface coating that is substantially solid and lacks foam or substantial porosity. Alternatively, the polyurea-type can be produced by selecting reactive amine compounds and isocyanates to develop the coated proppant. The coated proppants retain the discrete, free-flowing character of the original core solids but with the beneficial effects of the polyurea-type coating of the present invention.

Abstract: A water based solution having a controllable gel time is disclosed. The solution has predetermined ratios of a water soluble silicate solution having at least one alkali metal, a predetermined ratio of a water dispersible polymer, and a predetermined ratio of a water soluble initiator containing a reactive carbonyl compound.

Abstract: An improvement over known hydraulic fracturing fluids. Boundary layer kinetic mixing material is added to components of fracturing fluid wherein kinetic mixing material is a plurality of particles wherein at least 25% of particles are several types, i.e., having surface characteristics of thin walls, three dimensional wedge-like sharp blades, points, jagged bladelike surfaces, thin blade surfaces, three-dimensional blade shapes that may have shapes similar to a “Y”, “V” or “X” shape or other geometric shape, slightly curved thin walls having a shape similar to an egg shell shape, crushed hollow spheres, sharp bladelike features, 90° corners that are well defined, conglomerated protruding arms in various shapes, such as cylinders, rectangles, Y-shaped particles, X-shaped particles, octagons, pentagon, triangles, and diamonds.

Abstract: A plurality of solid particles including a thermoplastic composition having a softening temperature in a range from 50° C. to 180° C. and a blocked isocyanate resin; optionally at least some of the particles in the plurality of solid particles comprise both the thermoplastic composition and the blocked isocyanate resin. A composition comprising the plurality of particles dispersed in a fluid is also disclosed. A method of modifying a wellbore within a geological formation is also disclosed. The method includes introducing the fluid composition into the wellbore. A method of making a plurality of particles, for example, to use in the fluid composition, is also disclosed.

Abstract: Methods for creating a fluid diverting barrier in a zone of a subterranean formation are provided. Certain methods comprise providing a treatment fluid that comprises an aqueous base fluid, a viscoelastic surfactant, and a soap component; placing the treatment fluid in a subterranean formation penetrated by a well bore; and allowing the soap component of the treatment fluid to interact with a metal ion present in the subterranean formation to form a precipitate.

Abstract: The invention provides for modified proppants, comprising a proppant particle and a hydrogel coating, wherein the hydrogel coating localizes on the surface of the proppant particle to produce the modified proppant, methods of manufacturing such proppants and methods of use.

Abstract: A self-adaptive cement formulation includes cement, water, block copolymer and asphaltite-mineral particles. The set cement demonstrates self-healing properties when exposed to methane, and is particularly suited for well-cementing applications. After placement and curing, the self-healing properties help maintain zonal isolation should bonding be disrupted between the set cement and the formation or a casing string, should cracks or defects appear in the set-cement matrix, or both.

Abstract: Composition comprising a plurality of particulates wherein at least some particulates are at least partially covered with a coating that impedes the intrusion of water into the particulates; and, a silica scale control additive, wherein the silica scale control additive is capable of suppressing silica scale build-up proximate the plurality of particulates. Some compositions further include a treatment fluid wherein and the silica scale control additive are present in the treatment fluid.

Abstract: Fiber bundles are prepared by affixing at least two fibers with a binding agent. The binding agent is designed such that the fiber bundles remain intact as the fiber bundles are mixed with and suspended in a fluid. After the fiber bundles exit the mixing apparatus, the binding agent degrades and releases the individual fibers. This allows higher concentrations of fibers to be added to fluids without fouling the mixing apparatus.

Abstract: Of the many embodiments presented herein, one is a subterranean treatment fluid comprising: an aqueous fluid; and a water-soluble degradable synthetic vinyl polymer having a labile link in its backbone. Also provided in one instance is a water-soluble degradable synthetic vinyl polymer with labile group in its backbone made by a redox polymerization, the redox polymerization reaction comprising these reactants: a macroinitiator that comprises a labile link, an oxidizing metal ion, and a vinyl monomer.

Abstract: A method of treating a subterranean formation. The method may include providing a fluid loss control pill that comprises an aqueous base fluid, a gelling agent, and an internal breaker that is selected from the group consisting of inorganic delayed acids or inorganic salts. The method can include introducing the fluid loss control pill into a subterranean formation, allowing the internal breaker to reduce the viscosity of the pill after a delay period, and allowing the fluid loss control pill to break.

Abstract: Hydrophilic polymer particles have been obtained using polyacrylamide, xanthane, maleic anhydride polymers, allylamine, ethyleneimine, and oxazoline as core polymers. Then, hydrophobic polymers shells have been produced on the core-side using styrene, styrene copolymers, polyvinyl state, polysolfune, polymethyl methacrylate, and polycyclohxyl methacrylate by in-situ polymerization of monomer as method one and inverse emulsion process as method two. These particles can release hydrophilic polymers at oil-water interface at the reservoir temperature where the water flooding should have the maximum viscosity. So, active materials cause to decrease the mobility ratio of water to oil in the reservoirs and on the other hand, plug the swept porosities and prevent to act the water fingering process.

Abstract: Method and agent for reducing water production from oil and gas wells. The agent comprises polymer, cross-linked particles which are stable in water-free solvents. The particles are manufactured in an oil-in-oil emulsion and are cross-linked with at least one water-stable cross-linker and at least one water-labile cross-linker. The water-labile cross-linker is chosen so that when it is opened or broken in a reaction with water a hydrophilic seat is formed which increases the particle's ability to swell in water. The particles furthermore comprise a controlled amount of an immobilized chemical compound which by means of the reaction between water and reactive groups in the polymer skeleton, become able to form chemical bonds to another particle, to another reactive seat in the same particle or to another compounds thereby increasing the agent's stability in the formation.

Abstract: The invention is directed to polymer-enhanced proppant transport fluids, comprising a suspension fluid comprising a crosslinked synthetic polymer gel formulation, and a plurality of proppant particles. The invention also encompasses methods for improving production from an oil or gas well, methods of water blocking or water shutoff in an oil or gas well, methods of enhancing oil recovery from an oil source, methods of treating a petroleum-containing formation to reduce sand production, and methods of displacing fluid from a wellbore by viscous plug flow.

Abstract: An embodiment includes a method of servicing a well bore. The method may comprise introducing a lost circulation composition into a lost circulation zone, the lost circulation composition comprising hydraulic cement, nano-particles, amorphous silica, clay, and water. The method further may comprise allowing the lost circulation composition to set in the lost circulation zone. Another embodiment includes a lost circulation composition. The lost circulation may comprise hydraulic cement, nano-particles, amorphous silica, clay, and water.

Abstract: A well treatment composition comprises: an aqueous liquid; a fluid loss additive, wherein the fluid loss additive comprises a high molecular weight, water-swellable polymer; and an amphiphilic dispersant, wherein the well treatment composition has an activity of at least 10%. A method of cementing in a subterranean formation comprises: introducing a cement composition into the subterranean formation, the cement composition comprising: (i) cement; (ii) water; and (iii) the well treatment composition; and allowing the cement composition to set.

Abstract: A method includes providing a measured dose amount of manufactured metallic nanoparticle material and adding the measured dose amount of the manufactured metallic nanoparticle material to a sub-surface earth activity material to a sub-surface earth activity material for treatment corresponding to the sub-surface earth activity. A composition of silver in the form of silver nanoparticles in suspension having an interior of non-metallic material and a surface of silver dioxide, a maximum diameter less than about 100 nanometers, a minimum diameter of greater than about 2 nanometers, and biocidal properties.

Abstract: New hydrocarbon based slurry compositions and drilling, fracturing, completion and production fluids including the hydrocarbon based slurry composition are disclosed, where the composition includes a hydrocarbon soluble polymer adapted to decrease particle settling rates of particulate materials present in the fluids and in the case of fluids that include hydratable materials to increase hydration properties of such materials.

Abstract: A method for diverting fluids across a perforation tunnel in high-rate water pack operations may include providing a wellbore extending into a subterranean formation, wherein a perforation tunnel provides a fluid connection between the wellbore and the subterranean formation; providing a diverting particulate that comprises a degradable plasticized polymer coating on a particulate; placing the diverting particulate into the perforation tunnel, wherein the step of placing the diverting particulate forms a particulate pack within the subterranean formation and the perforation tunnel; allowing the degradable plasticized polymer coating to deform and fill the interstitial spaces within the particulate pack in the perforation tunnel such that the fluid conductivity between the wellbore and the subterranean formation is substantially blocked; and allowing the plasticized polymer coating to degrade over time thereby substantially restoring the fluid conductivity between the wellbore and the subterranean formation.

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: There is disclosed a process for transporting fracture fluid additives underground to oil and gas wells by attaching a fracture fluid additive to an ion exchange resin and flowing the ion exchange resin underground and thereafter releasing the frac fluid additives from the ion exchange resins and also there is provided the use of an ion exchange resin as a proppant and a frac fluid lubricant.

Abstract: A method of treating a zone of a subterranean formation penetrated by a wellbore, the method including the steps of: (a) forming a treatment fluid comprising: (i) water; (ii) a strong acid); (iii) a water-soluble polymer having at least one functional group that can be crosslinked with aluminum(III); (iv) a water-soluble aluminum carboxylate; and (v) a complexion agent for calcium ions; wherein the pH of the treatment fluid is less than the pH required for the aluminum to crosslink the polymer to form a crosslinked gel; (b) introducing the treatment fluid through the wellbore into the zone; and (c) allowing time for the strong acid in the treatment fluid to spend in the formation such that the pH of the fluid increases sufficiently for the aluminum of the aluminum carboxylate to crosslink the polymer.

Abstract: Trivalent-ion chelating agents may be useful in mitigating the formation aluminum and ferric precipitates in subterranean formations during acidizing operations. An acidizing operation may include introducing an acidizing fluid into a wellbore penetrating a subterranean formation, the acidizing fluid comprising an aqueous fluid, an acid source, and a trivalent-ion chelating agent, e.g., hydroxamates, 6,7-dihydroxyquinoline, 3-hydroxy-4-pyridinones, and any combination thereof. In some instances, trivalent-ion chelating agents with a pKa of less than about 7 may be particularly useful in acidizing operations.

Abstract: A method of servicing a wellbore in a subterranean formation comprising placing a wellbore servicing fluid comprising a resin-loaded expanded material into a wellbore wherein a resin is released from the resin-loaded expanded material in situ within the wellbore or subterranean formation. A wellbore treatment composition comprising a resin-loaded expanded material wherein the expanded material comprises polylactide and the resin material comprises a high-temperature epoxy-based resin.