Abstract: A sealant composition for servicing a wellbore comprising at least one gel system, a leak off prevention material and water.

Abstract: A method of servicing a wellbore comprising placing a composition comprising an emulsified resin composite into a fluid loss zone of the wellbore, wherein the emulsified resin composite comprises a nonaqueous external phase (NEP) and an aqueous internal phase (AIP), and allowing the composition to cure to form a composite material.

Abstract: A method for treating a subterranean formation penetrated by a wellbore is provided. The method includes providing a treatment fluid containing a viscoelastic surfactant having at least one degradable linkage, a hydrolysable material, and a pH control material, and injecting the treatment fluid into a subterranean formation. The pH control material may have a pH equal or greater than about 9 and may include a strongly alkaline material and an oxidizing agent.

Abstract: An apparatus and device for hydrocarbon recovery in a well for coal bed methane (CBM) recovery, tight sand gas extraction, and other gas extraction techniques provides for the formation of a hydrocarbon foam comprised of a fluid delivered into a downhole portion of the well and the hydrocarbon, maximizing water removal for gas recovery. The apparatus may include a check valve that feeds a nozzle to deliver or atomize the spray of fluid into the downhole portion of the well when the pressure applied to the fluid is sufficient to overcome a hydrostatic pressure in the downhole portion of the well and to deliver the fluid into the downhole portion of the well. The fluid is not sprayed directly into the formation, thereby protecting the formation from damage and recovering the fluid even in the case where water is not present. The capillary tube feeding the fluid to the check valve may be placed externally to the production tube to facilitate ease of cleaning and clearing of the production tube.

Abstract: A method, apparatus and composition are described for safe energy delivery down hole resulting in increased recovery of subterranean hydrocarbons. The method utilizes the reaction of non-alkane fuels and selective oxidizers which are non-selective toward alkane chemical compounds. The energy released in the subterranean reaction is utilized to heat the wellbore, the formation or the formation hydrocarbons thereby lowering fluid viscosity and permitting greater flow especially for heavy oils. Further, safe delivery of oxidizers can be accomplished without limit on depth as the selective oxidizer may be delivered to point of use down hole as most all formations of interest contain primarily alkane hydrocarbons and will not react with the non-alkane selective oxidizer. In addition some products of reaction may be insoluble in water and can be utilized for fluid loss prevention, flow diversion, abrasive drilling and or as proppants.

Abstract: The toughness of set cement may be enhanced by incorporating partially cured waterborne resins in the cement matrix. A hardening agent is added to the waterborne resin, and the mixture is allowed to react for periods between about 1 min and 15 min. The waterborne resin with hardening agent is then combined with an inorganic cement to form a pumpable slurry.

Abstract: An encapsulated thixotropy agent may be added to aqueous well service fluids. Such fluids include drilling fluids, cement slurries and polymer pills. The well service fluid may be subjected to shearing action downhole, causing the thixotropy agent to be released and imparting thixotropy to the fluid. The thixotropy agent comprises a dry suspension of synthetic layered silicates.

Abstract: The current application discloses compositions and methods for treating a subterranean formation. CO2 swellable elastomers can be used in a treatment fluid to at least partially block a high permeability region, therefore improving the performance of an operation such as matrix stimulation, acidizing, and acid fracturing.

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: A silicate gel composition that is useful for sealing the face of a fracture of a formation. A method of sealing a face of a fracture of a formation with the silicate gel composition and diverting an acid treatment fluid.

Abstract: Methods for preventing or alleviating the loss of drilling fluids and other well treatment fluids into a subterranean formation during drilling or construction of boreholes therein include a drilling fluid including a lost circulation material. The lost circulation material includes a suspension of swelled particles of a pH sensitive polymeric material, the swelled particles capable of reversibly attaching to other swelled particles of the polymeric material. The pH of the aqueous solution is such that each particle of the swelled pH sensitive polymeric material is not attached to other swelled particles, and wherein upon lowering the pH of the suspension, the swelled particles attach to each other.

Abstract: Anhydrous borate compounds can be used in a variety of subterranean treatment operations, where particulates of the anhydrous borate compounds slowly become soluble in an aqueous fluid after facilitating the treatment operation. Cleanup fluids can be used for affecting a more rapid removal of the anhydrous borate compounds from a subterranean formation. Methods for performing a cleanup of anhydrous borate compounds within a subterranean formation can comprise providing a cleanup fluid comprising a polyhydroxylated compound, introducing the cleanup fluid into a subterranean formation having a plurality of anhydrous borate particulates therein, and interacting the polyhydroxylated compound with the anhydrous borate particulates such that the anhydrous borate particulates become soluble in an aqueous fluid.

Abstract: A particulate suspending agent may be useful for mitigating particulate settling in wellbore applications with high-temperature and/or at near-neutral and higher pH values. Methods of treating a wellbore may include providing a treatment fluid comprising an aqueous liquid, a plurality of particulates, and a particulate suspending agent, wherein the particulate suspending agent comprises a crosslinked polymer particulate formed by a reaction comprising a first monofunctional monomer and an orthoester crosslinker, the orthoester crosslinker comprising an orthoester linkage and at least two crosslinking moieties; and placing the treatment fluid in a wellbore penetrating a subterranean formation.

Abstract: Methods and compositions are disclosed that comprise interground perlite and hydraulic cement. An embodiment provides a method of cementing comprising: providing a settable composition comprising perlite, hydraulic cement, and water, wherein the perlite and hydraulic cement are interground prior to combination with the water to form the settable composition; and allowing the settable composition to set.

Abstract: A composition flowing along an elongate conduit to a location accessed by that conduit contains a precursor substance which, arriving at the location, is converted electrochemically to chemically reactive intermediate. This intermediate reacts with another constituent of the composition, thereby bringing about a change in the composition. The reactive intermediate may be a cross-linking agent for a polymeric constituent of the composition so that the electrochemical reaction and subsequent cross-linking increases the viscosity of the composition as it arrives at the location where it is required.

Abstract: The present invention includes methods and compositions relating to the setting of fluids or slurries in a wellbore. In one embodiment, a method of isolating a portion a wellbore includes preparing a sealant composition having a fluid component, a polymeric additive constituent, and a set modifier component. The sealant composition is placed into a wellbore and subjected to ionizing radiation. The ionizing radiation can cause bonding between polymeric additive constituents and create a polymer matrix within the sealant composition that increases the mechanical strength of the sealant composition. The ionizing radiation also alters the set modifier component, triggering the thickening of the sealant composition.

Abstract: The present invention relates to methods and compositions that can be used to delay crystallization of a treatment solution so that thief zones or fractures are plugged in subterranean formations at a substantial distance from a wellbore. A supersaturated sodium aluminate solution, or other solutions, are introduced into the reservoir. The solution is relatively stable in the supersaturated state. Crystallization, or de-stabilizing the solution, can be controlled, which in turn plugs the thief zone or fracture at a designed point of time. By controlling the time that crystallization starts, i.e., the induction period, thief zones that are located at a substantial distant from the wellbore can be plugged.

Abstract: A method, system, and composition for producing oil from a formation utilizing an oil recovery formulation comprising a surfactant, an alkali, a polymer, and a paraffin inhibitor are provided.

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: A method and apparatus for the management of injection and production of well fluids in a subterranean well is described to optimize the use of stimulation fluids to enhance their compatibility with subterranean reservoirs and the surface environment and thereby reducing the damage said fluids induce in subterranean reservoirs and upon flow back to the surface reduce their damage to the environment is described. More specifically, this method is directed to the subterranean treatment of injection fluids.

Abstract: The uncontrolled flow of fluid from an oil or gas well may be reduced or stopped by injecting a composition including 2-cyanoacrylate ester monomer into the fluid stream. Injection of the monomer results in a rapid, perhaps instantaneous, polymerization of the monomer within the flow stream of the fluid. This polymerization results in formation of a solid plug that reduces or stops the flow of additional fluid from the well.

Abstract: A method includes treating a first formation intersecting a wellbore, preparing a diversion fluid including an inactivated viscosifier and an inactivated thinning agent, and positioning an amount of the diversion fluid to isolate the first formation. An activator is then delivered to the diversion fluid, thereby activating the inactivated viscosifier and triggering a thinning agent activation process.

Abstract: In one aspect of the present invention, an external tubular member comprises an external outside surface and an external inside surface joined by an external wall thickness. The external wall thickness comprises external sintered polycrystalline diamond. An internal member comprises an internal outside surface and an internal width. The internal width comprises internal sintered polycrystalline diamond. The external inside surface is adjacent to the internal outside surface.

Abstract: A method of treating a portion of a subterranean formation that includes: providing a water-in-oil emulsion, inverting the water-in-oil emulsion to form a friction reducing treatment solution, and introducing the treatment solution into the portion of the subterranean formation. The water-in-oil emulsion has an oil phase, an aqueous phase and surfactants. The oil phase (O) and an aqueous phase (A) are present at an O/A ratio of from about 1:8 to about 10:1. The oil phase is present as a continuous phase and contains an inert hydrophobic liquid. The aqueous phase is present as a dispersed phase of distinct particles in the oil phase and includes water and a water soluble polymer. The water soluble polymer makes up from 10 to 25 weight percent of the water-in-oil emulsion. The water-in-oil emulsion is inverted by adding it to water to form a friction reducing treatment solution.

Abstract: A method of servicing a wellbore in contact with a subterranean formation comprising placing a wellbore servicing fluid comprising a polyuronide polymer within the wellbore, contacting the wellbore servicing fluid with a divalent ion source, and allowing the wellbore servicing fluid to form a gel within the wellbore wherein the divalent ion source is located within the wellbore. A method of servicing a wellbore in contact with a subterranean formation comprising (a) placing a wellbore servicing fluid comprising a polyuronide polymer into the wellbore wherein the wellbore servicing fluid contacts a calcium ion source, (b) shutting the wellbore and allowing the servicing fluid to set into place for a period of time, and (c) repeating steps (a) and (b) until the permeability of a structure within the wellbore is reduced by about 50%.

Abstract: A water treatment system for producing a sodium hypochlorite solution to control bacteria levels in well water containing: a pH adjuster; a container containing solid calcium hypochlorite for producing a calcium hypochlorite solution; and a container containing solid sodium carbonate for producing the sodium hypochlorite solution and a method of controlling bacteria levels in well water by using intermittent injections of a sodium hypochlorite solution with alternating pH values.

Abstract: The current application discloses methods and systems for generating high pressure dual phase mixture. In some embodiments, the methods and systems involve mounting a dual phase mixture generator on a transportable platform wherein the dual phase mixture generator comprises a mixing chamber connected with at least a first inlet, a second inlet, and a first outlet. A first container and a first pump are also mounted on the transportable platform wherein the first pump is operably connected with the first container. The transportable platform and the mounted equipments are then deployed at a wellsite. A base fluid is pumped into the first inlet under high pressure, and a gas is pumped into the second inlet under high pressure. The base fluid and the gas is combined in the mixing chamber to generate a high pressure dual phase mixture, which is then discharged via the outlet.

Abstract: Disclosed herein is a fracturing fluid comprising a carrier fluid; a polymer that is soluble in the carrier fluid; the polymer being a synthetic polymer, wherein the synthetic polymer comprises a labile group that is operative to facilitate decomposition of the synthetic polymer upon activation of the labile group; the polymer being crosslinked, the fracturing fluid having a viscosity of about 200 to about 3000 centipoise at 100 s?1; and an oxidizing agent. A method for treating a hydrocarbon-bearing formation is also disclosed herein.

Abstract: Disclosed herein is a fracturing fluid comprising a carrier fluid; a polymer that is soluble in the carrier fluid; the polymer being a synthetic polymer, wherein the synthetic polymer comprises a labile group that is operative to facilitate decomposition of the synthetic polymer upon activation of the labile group; the synthetic polymer being operative to increase the viscosity of the carrier fluid to about 5 to about 50 centipoise; the fracturing fluid being operative to reduce friction during a downhole fracturing operation and to transport a proppant during the downhole fracturing operation; and an oxidizing agent. A method for treating a hydrocarbon-bearing formation is also disclosed herein.

Abstract: Viscoelastic surfactant (VES) gelled aqueous fluids containing water, a VES in an amount effective to increase the viscosity of the water, and an internal breaker may be useful in removing a residual polymer from a hydraulic fracture. Optionally, a pseudo-crosslinker may be present to further improve the properties related to treatment fluid placement and polymer clean-up. A plurality of aliquots of VES gelled fluid may be injected into a subterranean formation. A stop-start interval may exist between the injection of each aliquot. The VES gelled fluid may contact at least some of the residual polymer in the hydraulic fracture, and a broken fluid is formed once the viscosity of the VES gelled fluid is reduced with the internal breaker. At least a portion of the residual polymer and a majority of the broken fluid may be removed.

Abstract: A method of hydraulic fracturing is provided which uses metal silicides to generate significant pressure inside a wellbore. The method comprises injecting a fracturing fluid and an aqueous or reacting fluid into the wellbore to react with the fracturing fluid. The fracturing fluid comprises metal silicide, which may be uncoated or coated, and hydrocarbon fluid. The aqueous fluid comprises water. The reacting fluid comprises water or a solvent. A method of removing buildup in pipelines such as subsea pipelines which uses metal silicides to generate heat and pressure inside the pipeline is also provided. The method comprises injecting an organic slug and an aqueous slug. The organic slug comprises metal silicide and hydrocarbon fluid. The aqueous slug comprises water. Alternatively, there is also provided a method for purifying flowback water produced from a hydraulic fracturing process comprising adding metal silicide to the flowback water produced from a hydraulic fracturing process.

Abstract: A composition comprises: a treatment fluid comprising a lost-circulation material, wherein the lost-circulation material comprises asphalt, and wherein the lost-circulation material has a median particle size in the range from about 0.001 millimeters to about 25.4 millimeters. According to another embodiment, the composition comprises: a treatment fluid comprising a lost-circulation material, wherein the lost-circulation material comprises asphalt, and wherein the median particle size and the concentration of the lost-circulation material is selected such that the treatment fluid has a sealing pressure of at least 30 psi (0.2 MPa). A method of eliminating or reducing lost circulation from a well comprises: introducing the treatment fluid into at least a portion of the well.

Abstract: The present invention relates to a process for the production of mineral oil from mineral oil deposits with large temperature gradients, in which, for increasing the mineral oil yield, highly permeable regions of the mineral oil formation are blocked by injecting formulations which, after being forced into the deposit, form highly viscous gels under the influence of the deposit temperature. A plurality of portions of the formulation which in each case can form gels at different temperatures and therefore result in very complete blocking of highly permeable regions of the formation are used.

Abstract: A method of gravel packing a hole in a subterranean formation having a filter cake coated on the surface thereof is disclosed. The method may include: injecting into the hole a gravel pack composition comprising gravel and a carrier fluid comprising a base fluid and at least one alkyl glycoside. Also disclosed is a solution including an aqueous fluid, at least one alkyl glycoside, and gravel which may be used as a composition for a gravel pack operation, for example.

Abstract: A method for treating a wellbore in a hydrogen sulfide-containing formation that includes injecting a first slug in the wellbore, the first slug comprising: at least one of primary amine and ammonia; and a base fluid; injecting a second slug in the wellbore, the second slug comprising: a triazine scavenger; and a base fluid; and allowing the triazine scavenger to react with the hydrogen sulfide is disclosed.

Abstract: A hydrocarbon-bearing subterranean formation may be treated with an aqueous well treatment fluid which contains a hexose oxidase, such as glucose oxidase, mannose oxidase or galactose oxidase. The aqueous well treatment fluid further may contain a viscosifying polymer and an aldohexose. The aldohexose reacts in-situ with the hexose oxidase and molecular oxygen to produce hydrogen peroxide. The hydrogen peroxide may then act as a breaker.

Abstract: Delayed-tackifier coated particulates and treatment fluids comprising delayed-tackifier coated particulates wherein the tackifier is associated with a surfactant. The treatment fluids may be used in methods that include providing a treatment fluid that comprises an aqueous base fluid and a delayed-tackifier coated particulate and introducing that treatment fluid into a wellbore penetrating a subterranean formation. Once within the formation, forming a particulate pack, wherein the particulate pack is a gravel pack along a portion of the wellbore, a proppant pack within a portion of the subterranean formation, or both.

Abstract: The invention relates to methods and compositions for producing or recovering an aqueous-based fluid to be utilized or injected in a wellbore or surrounding subterranean formation. The method comprises the step of contacting an aqueous-based fluid with an aqueous-soluble breaker composition comprising an oxidizing agent and a catalyst for a time sufficient to reduce or eliminate one or more deleterious substances in the aqueous-based fluid to produce a treated aqueous-based fluid suitable for use or injection in a wellbore or surrounding subterranean formation.

Abstract: The invention provides economically effective methods for hydraulic fracturing a subterranean formation that ensure improvement of the hydraulic fracture conductivity because of forming strong proppant clusters uniformly placed in the fracture throughout its length. One of these methods comprises: a first stage comprising injection of fracturing fluid into a borehole, the fluid containing thickeners to create a fracture in the formation; and a second stage comprising introduction of proppant into the injected fracturing fluid to prevent closure of the created fracture, and further, comprising introducing an agent into the fracturing fluid to provide formation of proppant clusters in the created fracture and channels for flowing formation fluids.

Abstract: An isolation element includes a body having at least one sealing surface, an internal cavity within the body, and a chemical agent disposed within the internal cavity. The chemical agent is configured to substantially increase a rate of degradation of the body.

Abstract: A composition comprising a fluorinated pyridinium cationic compound of formula (I) wherein Rf is R1(CH2CH2)n—, R1 is a C7 to C20 perfluoroalkyl group interrupted by at least one catenary oxygen atom, each oxygen bonded to two carbon atoms, n is an integer of 1 to 3, and R is H, C1 to C5 linear or branched alkyl, or C1 to C5 linear or branched alkoxy, having surfactant properties for lowering surface tension in an aqueous medium or solvent medium, and for use as a foaming agent.

Abstract: A foam generating surfactant formulation includes a betaine, an alpha-olefin sulfonate and a nanofluid. The betaine is preferably a cocamidopropyl betaine or laurel betaine. The alpha-olefin sulfonate is preferably an anionic surfactant having between 8 and 18 carbon atoms per molecule. The nanofluid is preferably an oil-in-water nanofluid that includes an emulsifying surfactant, a solvent, a co-solvent and water. The addition of the nanofluid increases the thermal stability and salt resistance of the foam generating surfactant.

Abstract: Methods are provided for treating production fluid in an oil reservoir to reduce the amount of sulfide in the production fluid. The production fluid is treated with nitrate and/or nitrite ions in an aqueous solution that is added to an injection well that is in contact with the production well.

Abstract: Improved treatment fluids and methods for use in subterranean operations including the treatment of low permeability shale formations. In one embodiment the methods comprise: providing a treatment fluid comprising an aqueous base fluid and a controlled wetting system that comprises: a water soluble polymer having a charge, a surfactant having an opposite charge, and a compatibilizer; and introducing the treatment fluid into a subterranean formation.

Abstract: A method of forming a gelled liquid hydrocarbon treatment fluid is disclosed. The method comprises combining a liquid hydrocarbon, a phosphoric acid ester and a pre-mixed solution comprising water, ferrous ion (Fe2+) and an amine; and forming the gelled liquid hydrocarbon treatment fluid. A method of treating a portion of a subterranean formation is also disclosed and comprises: providing a gelled liquid hydrocarbon treatment fluid, by combining a liquid hydrocarbon, a phosphoric acid ester and a pre-mixed solution comprising water, ferrous ion and an amine, and treating the portion of the subterranean formation with the gelled liquid hydrocarbon treatment fluid.

Abstract: Among many things, compositions and methods relating to the prevention and remediation of surfactant gel damage are provided. In one embodiment, the method includes providing a treatment fluid comprising a carrier fluid; at least one component selected from the group consisting of a chelating agent and a scale control agent; at least one component selected from the group consisting of an alcohol, a glycol, a pH modifier, a hydrocarbon, a mutual solvent, an oxidizer, a reducer, an enzyme, a transition metal, a combination thereof, and a derivative thereof; and at least one component selected from the group consisting of a nonemulsifier, a demulsifier, a combination thereof, and a derivative thereof, and introducing the treatment fluid into a subterranean formation.

Abstract: Gellable treatment fluids may have their gel times modified by using a polymer mixture therein that contains two or more polymers having disparate average molecular weights. Methods for treating a subterranean formation using such gellable treatment fluids can comprise providing a gellable treatment fluid comprising a polymer mixture and a crosslinking agent, introducing the gellable treatment fluid into a subterranean formation, and allowing the gellable treatment fluid to form a gel in the subterranean formation. The polymer mixture comprises a base polymer and an addend polymer, where the base polymer and the addend polymer each comprise an acrylamide monomer unit or a derivative thereof and have different average molecular weights, such that a molecular weight distribution of the polymer mixture contains at least two local maxima.

Abstract: Treatment fluids can mitigate the occurrence or effects of precipitation in a subterranean formation through complexation of a metal ion therein. Methods for treating a subterranean formation can comprise: providing a treatment fluid comprising a hydroxypyridinecarboxylic acid, a salt thereof, or a tautomer thereof; introducing the treatment fluid into a subterranean formation; and complexing a metal ion in the subterranean formation with the hydroxypyridinecarboxylic acid.

Abstract: Voids (14) in a underground wellbore (1) are sealed by:—inserting a corrosion prone object (10A-C, 12) in the void injecting an oxidizing agent into the void (14); and—allowing the oxidizing agent to induce corrosion of the corrosion prone object and to thereby generate corrosion products (13A-E) that are physically larger than the corrosion prone object (10A-C, 12) and that seal the void (14).

Abstract: A wellbore servicing method comprising circulating an invert emulsion fluid through a wellbore to form a filter cake within the wellbore, wherein the invert emulsion fluid comprises an oleaginous fluid, a non-oleaginous fluid, and an acid-sensitive surfactant, contacting at least a portion of the filter cake with an emulsion reversing fluid, wherein the emulsion reversing fluid comprises an acid precursor, wherein the acid precursor is not an acid, and wherein the acid precursor is configured to generate a quantity of acid after a predetermined delay period beginning at placement within a wellbore, allowing the emulsion reversing fluid to remain in contact with the filter cake for a soak period, and removing the filter cake from the wellbore.