Abstract: A cement slurry composition comprises a plugging agent with a glass-transition temperature lower than about 150° C. The plugging agent is preferably an including polyethlene wax, polypropylene wax, carnauba wax or scale wax. After the cement slurry sets, it may be heated to a temperature sufficient to melt the wax. The molten wax may then flow into pores in the set cement. Upon cooling, the wax solidifies. As a result, the porosity and permeability of the set cement are reduced.

Abstract: The present invention relates to methods useful for isolating a portion of a wellbore. In one embodiment, a method includes preparing a sealant composition containing a set modifier component. The sealant composition is placed into the wellbore and is subjected to ionizing radiation that alters the set modifier component, triggering the thickening of the sealant composition.

Abstract: The invention relates to a salt resistant water absorbing compound including a polymeric phase that includes polyacrylamide and at least one of di or poly saccharide, wherein the polyacrylamide is cross-linked in the presence of at least one of di or poly saccharide by a cross-linking agent including multivalent cations, complexes thereof, organic cross-linking agents, or any combination thereof.

Abstract: Method of treating a subterranean formation comprising providing a consolidation fluid, introducing the resin consolidation fluid into a subterranean formation comprising unconsolidated particulates; and, curing the resin to at least partially consolidate the unconsolidated particulates. The consolidation fluid comprises a resin in emulsified form with an aqueous external phase and an organic internal phase wherein the emulsified resin does not comprise a hardening agent and an aqueous base fluid that further comprises a hardening agent. The consolidation fluid may further comprise an emulsifying agent.

Abstract: A method of preparing and using a subterranean formation stabilization agent. The stabilization agent includes a guanidyl copolymer and may be admixed with a fracturing fluid and optionally brine. The stabilization agent is effective in preventing and/or reducing, for example, clay swelling and fines migration from a subterranean formation contacted with the stabilization agent.

Abstract: The invention discloses a method of creating a polymerized composition in a well bore: providing a polymerizable composition made of a polymerization initiator and a monomer polymerizable by frontal polymerization; introducing the polymerizable composition into the wellbore; exposing the polymerizable composition to a trigger to activate the frontal polymerization; and creating the polymerized composition.

Abstract: A method of removing a partial amount of water in a well, comprises deploying a differential filter downhole; and performing a downhole operation, wherein the differential filter comprises a swellable polymer that swells after contacting water such that permeability of the differential filter is reduced by removing said partial amount of water, the swellable polymer being non-soluble in the water and/or hydrocarbon and wherein the swellable polymer comprises at least one selected from the group consisting of polyacrylic acid, polyacrylate, polymethacrylic acid, poly maleic anhydride, polyacrylamide, polyvinyl alcohol, latex, polyamide, polyester, and a co-polymer thereof.

Abstract: This invention relates to the use of degradable fibers, and more particularly, to self-degrading fibers and their associated methods of use and manufacture. In one embodiment, the present invention provides a self degrading fiber comprising: an outer shell, and a core liquid.

Abstract: The present invention includes methods relating to the setting of fluids or slurries in a wellbore. In one embodiment, a method of isolating a portion a wellbore by preparing a sealant composition comprising a fluid component and a polymeric additive component, placing the sealant composition into a wellbore and subjecting the sealant composition to ionizing radiation. The ionizing radiation can cause bonding between polymeric additive components and create a polymer matrix within the sealant composition that increases the mechanical strength of the sealant composition.

Abstract: Methods and compositions are provided that relate to cementing operations. Methods and compositions that include a latex strength enhancer for enhancing the compressive strength of slag compositions.

Abstract: Methods and compositions are provided that relate to cement compositions and methods comprising sub-micron calcium carbonate and latex. An embodiment includes a method of cementing in a subterranean formation. The method may comprise introducing a cement composition into the subterranean formation, wherein the cement composition comprises cement, water, sub-micron calcium carbonate, and latex. The method further may comprise allowing the cement composition to set in the subterranean formation. Another embodiment includes a cement composition that may comprise cement, water, a sub-micron calcium carbonate, and latex.

Abstract: Crosslinkable polymer compositions are provided that may be useful for, among other things, reducing, stopping, or diverting the flow of fluids in subterranean formations. The crosslinkable polymer compositions may comprise an aqueous fluid, a chitosan-reacting polymer, chitosan, and a gelation-retarding additive comprising an acid derivative. Various methods of use are also provided.

Abstract: A method of preparing and using a subterranean formation stabilization agent. The stabilization agent includes a guanidyl copolymer and may be admixed with a fracturing fluid and optionally brine. The stabilization agent is effective in preventing and/or reducing, for example, clay swelling and fines migration from a subterranean formation contacted with the stabilization agent.

Abstract: The present invention relates to compositions useful for isolating a portion of a wellbore. In one embodiment, a composition includes a sealant composition containing a wellbore treatment fluid and a set modifier component. The sealant composition can be placed into the wellbore and subjected to ionizing radiation that alters the set modifier component, triggering the setting of the sealant composition.

Abstract: The present invention includes compositions relating to the setting of fluids or slurries in a wellbore. In one embodiment, a sealant composition having a fluid component and a polymeric additive component can be subjected to ionizing radiation. The ionizing radiation can cause bonding between polymeric additive components and create a polymer matrix within the sealant composition that increases the mechanical strength of the sealant composition.

Abstract: Methods suitable for use in a subterranean formation utilizing particulates coated with both a tackifier and a resin.

Abstract: Methods useful in treating subterranean formations to control particulate migration with a tacky-consolidate treatment fluid comprising a resin and a tackifying compound. One method comprises the steps of providing a portion of a subterranean formation comprising unconsolidated particulates; providing a tacky-consolidate treatment fluid comprising a tackifying compound, a curable resin, and a silane coupling agent; and placing the tacky-consolidate treatment fluid in the subterranean formation so as to form a tacky consolidate that comprises at least a portion of the unconsolidated particulates.

Abstract: A completion tubular is placed in position adjacent the zone or zones to be fractured and produced. It features preferably sliding sleeve valves one series of which can be put in the wide open position after run in for gravel packing and fracturing zones one at a time or in any desired order. These valves are then closed and another series of valves can be opened wide but with a screen material juxtaposed in the flow passage to selectively produce from one or more fractured zones. An annular path behind the gravel is provided by an offset screen to promote flow to the screened production port. The path can be a closed annulus that comes short of the production port or goes over it. For short runs an exterior screen or shroud is eliminated for a sliding sleeve with multiple screened ports that can be opened in tandem.

Abstract: The invention relates to the use of one or more water-soluble reactive liquid component capable of subsequent polymerization or cross-linking to form a solid to improve the zonal isolation and alleviate the impacts of cracks and fissures in the cement sheath around a completed subterranean well. It includes the steps of injecting a wellbore fluid carrying the reactive component or additive into the wellbore, injecting a cementitious composition as slurry into the wellbore and letting said reactive liquid component pass through at least one of the interfaces between cement and formation, cement and filter cake, and filter cake and formation before forming a solid of said reactive liquid component that traverses said at least one of the interfaces.

Abstract: Methods and compositions useful for subterranean formation treatments, such as hydraulic fracturing treatments and sand control that include porous materials. Such porous materials may be selectively configured porous material particles manufactured and/or treated with selected glazing materials, coating materials and/or penetrating materials to have desired strength and/or apparent density to fit particular downhole conditions for well treating such as hydraulic fracturing treatments and sand control treatments. Porous materials may also be employed in selected combinations to optimize fracture or sand control performance, and/or may be employed as relatively lightweight materials in liquid carbon dioxide-based well treatment systems.

Abstract: Methods including the steps of providing an injection well having unconsolidated particulates in one or more formation intervals along the wellbore that accept injection fluid; providing a consolidating treatment fluid comprising a base fluid and a consolidating agent; introducing the consolidating treatment fluid through the injection well, while the well is under injection, such that the consolidating treatment fluid enters into a portion of a formation interval along the wellbore that accepts injection fluid; and, allowing the consolidating fluid to consolidate formation particulates therein. The methods may be performed such that the percentage of consolidating agent varies over the course of the treatment or the rate of injection varies over the course of the treatment.

Abstract: Methods and compositions that include a method comprising: providing a treatment fluid comprising at least a plurality of degradable diverting agents that comprise at least one degradable material selected from the group consisting of a fatty alcohol, a fatty acid salt, a fatty ester, a proteinous material, and a combination thereof; and introducing the treatment fluid into a subterranean formation during a subterranean operation via a well bore.

Abstract: The methods described herein generally relate to preparing and delivering a fluid mixture to a confined volume, specifically an annular volume located between two concentrically oriented casing strings within a hydrocarbon fluid producing well. The fluid mixtures disclosed herein are useful in controlling pressure in localized volumes. The fluid mixtures comprise at least one polymerizable monomer and at least one inhibitor. The processes and methods disclosed herein allow the fluid mixture to be stored, shipped and/or injected into localized volumes, for example, an annular volume defined by concentric well casing strings.

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 composition for treating a subterranean formation is formed from water, a water-soluble polymer and a crosslinking system. The crosslinking system utilizes 1) primary crosslinking agent of at least one of a dialdehyde benzene source, a dioxane, and a trioxane, 2) a secondary low temperature organic crosslinking agent that generates aldehyde, and 3) a phenol source. The crosslinking system provides the composition a delayed gel time of about 2 to about 20 hours at temperatures of about 250° F. (121° C.) or higher. A method of treating a subterranean formation penetrated by a wellbore is also accomplished by forming a treatment fluid from the composition and introducing the treatment fluid into the formation through the wellbore.

Abstract: Methods of enhancing the conductivity of fractures in subterranean formations comprising: providing a propped fracture in a subterranean formation wherein a plurality of proppant particulates reside in at least a portion of the fracture; providing a displacement fluid; introducing the displacement fluid into the propped fracture in the subterranean formation at a rate that is at least the matrix rate of the subterranean formation; and allowing the displacement fluid to displace at least a portion of the plurality of proppant particulates, thereby forming at least one channel in the propped fracture.

Abstract: Sealant compositions comprising a colloidally stabilized latex and methods of using the same to service a wellbore are provided. The sealant compositions may include: an aliphatic conjugated diene monomer; an additional monomer comprising a non-aromatic unsaturated mono- or di- carboxylic ester monomer, an aromatic unsaturated monomer, a nitrogen-containing monomer, or combinations thereof; and a protective colloid. The foregoing sealant composition may be displaced into the wellbore to isolate the subterranean formation from a portion of the wellbore, to support a conduit in the wellbore, to plug a void or crack in the conduit, to plug a void or crack in a cement sheath disposed in an annulus of the wellbore, to plug an opening between the cement sheath and the conduit, or combinations thereof. The colloidally stabilized latex remains substantially stable when exposed to salt, which may be present in the wellbore and/or in the sealant composition itself.

Abstract: A metal implant, in particular a dental implant, with a hydrophilic surface for at least partial insertion into a bone, and a method for the production of said implant are described. A particularly advantageous hydrophilic surface for improved osteointegration properties is made available if it is briefly treated, at least in some areas, in a weakly alkaline solution. These excellent osteointegration properties can be achieved in a method in which, optionally after a preceding mechanical surface modification by material removal and/or chemical surface modification, at least the areas exposed of this surface exposed to bone and/or soft tissue are chemically modified in an alkaline solution.

Abstract: The present disclosure is directed to a system and method for sonically activating cement slurries. In some implementations, a method of treating a subterranean formation includes positioning a settable composition including a capsule in a wellbore. The capsule is used to increase a setting rate in response to at least sonic signals. A sonic signal is transmitted to at least a portion of the settable composition to release an activator from the capsule.

Abstract: A process for the preparation of hydrolytically and hydrothermally stable consolidated proppants is described, in which (A) a consolidating agent comprising (A1) a hydrolysate or precondensate of at least one functionalized organosilane, a further hydrolyzable silane and at least one metal compound, the molar ratio of silicon compounds used to metal compounds used being in the range of 10 000:1 to 10:1, and (A2) an organic crosslinking agent are mixed with a proppant and (B) the consolidating agent is cured at elevated pressure and elevated temperature. The consolidated proppants obtained have high mechanical strength.

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 unexpanded volume average particle size diameters of from about 0.05 to about 5,000 microns and cross linking agent contents of from about 100 to about 200,000 ppm of labile cross linkers and from 0 to about 300 ppm of non-labile cross linkers, wherein the expandable polymeric monomers have a block copolymer structure comprising at least two different monomers having different chemical structures.

Abstract: Treating a wellbore by providing a composition with at least one isocyanate including a blocking group able to be unblocked at or above a deblocking temperature; introducing the composition into the wellbore; contacting the composition with an inactivated catalyst and at least one active hydrogen compound; exposing the composition to a triggerable to activate the catalyst and to temperature above the deblocking temperature; and creating an elastomeric gel composition.

Abstract: Methods and compositions that include a resin composition having from about 5% to about 30% phenol, from about 40% to about 70% phenol formaldehyde, from about 10 to about 40% furfuryl alcohol, from about 0.1% to about 3% of a silane coupling agent, and from about 1% to about 15% of a surfactant and methods of using of that resin in controlling particulate flowback from a subterranean formation.

Abstract: The present disclosure is directed to compositions and methods 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 unexpanded volume average particle size diameters of from about 0.05 to about 5,000 microns and cross linking agent contents of from about 100 to about 200,000 ppm of labile cross linkers and from 0 to about 300 ppm of non-labile cross linkers that may be used in combination with other components such as, for example, a second and different polymeric microparticle, a viscosified aqueous solution, a subterranean reservoir treatment, or combinations thereof.

Abstract: An aqueous fluid having a viscosity greater than the viscosity of water is contacted with a water soluble material for a time and at a temperature sufficient to reduce the viscosity of the aqueous fluid to a value which is less than about 10 percent of the initial viscosity of the aqueous fluid. The water soluble material is an alkali metal peroxide or a combination of an alkali metal peroxide and a transition metal-containing compound.

Abstract: Wellbore treatment kits are provide that include a polymeric solution for placement in a wellbore that penetrates a subterranean formation and an activator for causing a polymer to precipitate out of the polymeric solution when it contacts the polymeric solution, wherein the resulting precipitate is capable of at least partially blocking a flow of a wellbore servicing fluid into the subterranean formation. The wellbore servicing fluid may be, for example, a drilling fluid, a cement composition, a workover fluid, or combinations thereof. The polymeric solution may comprise, for example, a poly vinyl pyrrolidone aqueous solution, and the activator may comprise, for example, a formate brine. When desirable, the precipitate may be easily and quickly removed from the subterranean formation by dissolving it in fresh water.

Abstract: A method of injecting a treatment fluid into a portion of a subterranean formation, comprising providing a treatment fluid having a viscosity; determining the breakdown pressure of the portion of the subterranean formation; calculating the maximum sustainable flow rate for the treatment fluid; and, injecting the treatment fluid into the portion of the subterranean formation at a flow rate less than or equal to the maximum sustainable flow rate for the treatment fluid. A method of injecting a treatment fluid into a portion of a subterranean formation, comprising providing a treatment fluid having a viscosity; determining the breakdown pressure of the portion of the subterranean formation; calculating the maximum allowable treatment fluid viscosity; adjusting the viscosity of the treatment fluid to a viscosity less than or equal to the maximum allowable treatment fluid viscosity; and injecting the treatment fluid into the subterranean formation at the selected treatment fluid flow rate.

Abstract: Disclosed embodiments relate to methods of completing wells in subterranean formations. An exemplary embodiment comprises forming an artificial barrier to water flow, wherein the artificial barrier is located at or above a hydrocarbon-water interface between a water-bearing formation zone and a hydrocarbon-bearing formation zone. The exemplary embodiment further comprises consolidating a portion of the hydrocarbon-bearing formation zone, wherein the artificial barrier is located between the consolidated portion of the hydrocarbon-bearing formation zone and the water-bearing formation zone.

Abstract: Methods and compositions are provided that relate to well bore treatments that comprise swellable particles. An embodiment includes a method that comprises introducing a fluid comprising a dual oil/water-swellable particle into a subterranean formation. Another embodiment includes a method of cementing that comprises: introducing a cement composition comprising cement, water, and a dual oil/water-swellable particle into a space between a pipe string and a subterranean formation; and allowing the cement composition to set in the space. Another embodiment includes a well treatment composition comprising a dual oil/water-swellable particle.

Abstract: This invention is directed to a composition comprising expandable polymeric microparticles comprising an interpenetrating polymer network (IPN). The IPN constrains the microparticle to an unexpanded volume average particle size diameter of from about 0.05 to about 5,000 microns. Labile cross-links in the polymers of the IPN are subject to degradation, which results in release of the expandable microparticle so that the microparticle expands. The invention is further directed to the use of the composition for modifying the permeability of subterranean formations and increasing the mobilization and/or recovery rate of hydrocarbon fluids present in the formations.

Abstract: Methods are described for drilling a wellbore through a production zone within a subterranean formation. Some of the methods use water-based consolidating emulsions that comprise an aqueous liquid and an emulsion comprising a hardening agent external phase and hardenable resin internal phase to drill along a production zone. Other methods use water-based consolidation emulsions that comprise a first emulsion comprising a hardenable resin internal phase and an aqueous external phase and a second emulsion comprising a hardening agent internal phase and an aqueous external phase to drill along a production zone.

Abstract: Disclosed herein is a coated particle comprising a substrate comprising an inorganic material, wherein the inorganic material comprises silica and alumina in a silica to alumina weight ratio of about 2.2 to about 5; and wherein the inorganic material has a bulk density of less than or equal to about 1 g/cm3; and a coating disposed upon the substrate. Disclosed herein too is a method of treating a subterranean formation comprising injecting a fracturing fluid into the subterranean formation; wherein the fracturing fluid comprises an inorganic particle that comprises silica and alumina in a silica to alumina weight ratio of about 2.2 to about 5; and wherein the inorganic particle has a bulk density of less than or equal to about 1 g/cm3.

Abstract: Methods are provided for reducing the loss of a wellbore servicing fluid to a subterranean formation. A polymeric solution and an activator may be contacted in the formation, thereby forming a precipitate to at least partially block fluid from flowing further into the formation. The fluid may be, for example, a drilling fluid, a cement composition, a workover fluid, or combinations thereof. The polymeric solution may comprise a polyvinylpyrrolidone aqueous solution, and the activator may comprise a formate brine. In one embodiment, the polymeric solution and the activator are contacted before completing a drilling operation in the wellbore. In another embodiment, they are contacted before completing a primary cementing operation in the wellbore. In yet another embodiment, they are contacted before completing a secondary cementing operation in the wellbore. When desirable, the precipitate may be easily and quickly removed from the subterranean formation by dissolving it in fresh water.

Abstract: A package and methods for treating a wellbore using the same. In one embodiment, the method comprises servicing a wellbore in contact with a subterranean formation by placing a material in the wellbore, wherein the material is disposed within a closed container. The material is suitable for use in a wellbore and is capable of plugging a flow pathway. The method further comprises releasing the material from the container. In an embodiment, the material is a swelling agent, which may plug a permeable zone.

Abstract: A method is provided for swelling hydrocarbon-swellable elements located in a portion of a well. The method comprises the steps of: (A) introducing a water-in-oil emulsion into the portion of the well, wherein the water-in-oil emulsion comprises: (i) a hydrocarbon liquid, wherein the hydrocarbon liquid is the external phase of the water-in-oil emulsion; (ii) an aqueous liquid, wherein the aqueous liquid is an internal phase of the water-in-oil emulsion and wherein the aqueous liquid is adjacent to the external phase of the water-in-oil emulsion; and (iii) a surfactant; and (B) allowing the water-in-oil emulsion to contact the hydrocarbon-swellable element for a sufficient length of time to cause the thickness of the hydrocarbon-swellable element to expand by a desired percentage, wherein the desired percentage is at least 5%.

Abstract: Methods are providing, including methods comprising providing a liner disposed within a well bore that penetrates a subterranean formation, such that the well bore comprises an annular space between the exterior surface of the liner and the well bore wall; providing a jetting tool disposed within the liner; introducing a stimulation fluid to a treatment interval of the well bore via the jetting tool, such that the stimulation fluid is introduced with sufficient pressure to create or enhance a plurality of perforations in the liner in the treatment interval; introducing a proppant slurry comprising a plurality of resin-coated particulates to the treatment interval of the well bore; and allowing the resin-coated particulates to fill at least a portion of the liner in the treatment interval and at least a portion of the annular space in the treatment interval.

Abstract: A process is described for replacing at least a portion of the liquid within the annular volume of a casing system within a wellbore with a second liquid. The second liquid is preselected to provide a measure of control of the pressure within the annular volume as the fluid within the volume is being heated.

Abstract: A sealant composition comprising an inverse emulsion polymer and methods of servicing a wellbore using the same are disclosed. In one embodiment, a method of servicing a wellbore that penetrates a subterranean formation is disclosed. The method comprises placing a sealant composition comprising an inverse emulsion polymer into the wellbore to reduce a loss of fluid to the subterranean formation during placement of the fluid in the wellbore.

Abstract: The invention discloses a well treatment composition for use in a subterranean formation comprising: a carrier fluid; and a viscoelastic surfactant being present in a concentration of less than about 1.5% by weight. Optionally, the fluid comprises a crosslinked polymer in a thickening amount in the carrier fluid. The invention also discloses a method to increase the viscosity of a fluid, the method comprising: providing a fluid comprising a thickening amount of a crosslinked polymer; adding a viscoelastic surfactant at a given concentration to the fluid; taking the fluid to a given temperature; defining a viscosity profile of the fluid depending of the concentration and the temperature; comparing said viscosity profile to a viscosity profile of the crosslinked polymer fluid alone; and defining an optimum concentration of the viscoelastic surfactant for each temperature.

Abstract: A temporary matrix is provided in treating a subterranean formation by providing a composition comprising a matrix forming material and a matrix degrading material. The matrix degrading material is capable of degrading the matrix after a period of time when subjected to existing or induced conditions of the subterranean formation. The composition is placed into a wellbore penetrating the subterranean formation. The composition is allowed to form a matrix within the wellbore, whereby the matrix at least one of significantly reduces the passage of fluid across or near the matrix or provides structural strength. A treatment operation is performed on the subterranean formation or wellbore and the degrading material is allowed to degrade the matrix.