Abstract: The technical challenges for a smooth transition between using both a thermodynamic hydrate inhibitor (THI) and a kinetic hydrate inhibitor (KHI) to simply using only the KHI in multiple tie-in gas natural gas production systems is solved by adding more THI in a first pipeline leg of the production system while ceasing adding THI in a second pipeline leg of the system. Further, more KHI is added into the second leg of the system, and subsequently THI is gradually and/or slowly reduced in the remaining legs of the system until only KHI is being injected, after which the KHI amount in all legs may be reduced to the equilibrium or steady-state levels.

Abstract: A method and composition for crosslinking a polymer based fluid includes providing a dry blend of crosslinker and delay agent. The crosslinker and delay agent are mixed and granulated in a dry form prior to addition to the polymer fluid.

Abstract: An acid-in-oil emulsion having a corrosion inhibitor as the external phase has been found to prevent downhole corrosion when acidizing carbonate formations to enhance hydrocarbon recovery.

Abstract: A method is provided for inhibiting scale in a hydrocarbon system, including the steps of: providing a hydrocarbon system; providing an aloe-derived scale inhibitor; and mixing the aloe-derived scale inhibitor with the hydrocarbon system in amounts effective to inhibit formation of scale. The scale inhibitor is an aloe vera gel/aloe sap mix dissolved in water at a concentration of between about 5 and about 50% wt/wt, which includes polysaccharides having a hydrocarbon chain structure having carboxyl and alcohol functional groups that interact with divalent ions.

Abstract: A method comprises providing a treatment fluid comprising an aqueous fluid, and a low-leakoff particulate, contacting a subterranean formation with the treatment fluid, and allowing the low-leakoff particulate to de-link so that at least a portion of the low-leakoff particulate enters the liquid phase.

Abstract: In one embodiment, the present invention provides a drilling fluid composition that comprises a surfactant-free emulsion comprising an oleaginous fluid, a fluid that is at least partially immiscible with the oleaginous fluid, and a non-surfactant polymeric emulsifier. In another embodiment, the present invention provides a method of treating a subterranean formation comprising providing a treatment fluid that comprises a surfactant-free emulsion, the surfactant-free emulsion comprising an oleaginous fluid, a fluid that is at least partially immiscible with the oleaginous fluid, and a non-surfactant polymeric emulsifier; and treating the subterranean formation.

Abstract: A method of decreasing the viscosity of a gelled organic-based fluid is disclosed. The method comprises combining an organic solvent, a gelling agent, and a metal crosslinker; forming the gelled organic-based fluid; and adding a chelating agent forming a complex with the metal to decrease the viscosity of the gelled organic-based fluid. The chelating agent may be chosen within nitrilotriacetic acid (NTA), citric acid; ascorbic acid, hydroxyethylethylenediaminetriacetic acid (HEDTA) or its salts, ethylenediaminetetraacetic acid (EDTA) or its salts, diethylenetriaminepentaacetic acid (DTPA) or its salts, phosphinopolyacrylate, thioglycolates, or a combination thereof.

Abstract: A method of treating a hydrocarbon reservoir that is penetrated by a well is disclosed, the method comprising injecting into the well a water transfer system comprising liquefied petroleum gas (LPG) and an alcohol that is at least partially water and liquefied petroleum gas soluble. Further, a method of treating a hydrocarbon reservoir is disclosed, the method comprising introducing into the hydrocarbon reservoir a combination of LPG and a solvent system that is at least partially liquefied petroleum gas and water soluble.

Abstract: The present invention relates to hydrophobically modified hydroxyalkyl guar derivatives which dissolve rapidly in water, having a hydroxyalkyl molar substitution between 0.2 and 2.5 and containing hydrophobic groups comprising C10-C32 alkyl chains, to the procedure for their preparation and to their use in the formulation of well fluids.

Abstract: A method of treating a well that includes selectively emplacing a fluid loss pill into the well, wherein the fluid loss pill includes at least one of diethylene glycol, triethylene glycol, and tetraethylene glycol, and wherein the at least one of diethylene glycol, triethylene glycol, and tetraethylene glycol reacts with a calcium brine present in the well to form a plug is disclosed.

Abstract: A method of cleaning a wellbore drilled with an oil-based drilling fluid that forms an oil-based filter cake where the method includes: emplacing a breaker fluid into the wellbore, the breaker fluid comprising: a water-miscible non-aqueous fluid; at least one weighting salt; and at least one breaking agent; and shutting in the well for a period of time sufficient to initiate breaking of the oil-based filter cake is disclosed.

Abstract: A liquid composition comprising a high-capacity aqueous carrier in which (i) a metalloid compound selected from the group consisting of antimony and germanium compounds and (ii) morpholine or derivative thereof are dissolved in the presence of (iii) unsaturated alcohol and (iv) water-soluble organic acid having reducing capacity, wherein the total concentration of said four components is preferably not less than 5% relative to the total weight of the composition. The composition is useful as a corrosion inhibitor. Also provided is a process for preparing the composition.

Abstract: An encapsulated reactant(s) having at least one encapsulant and at least one reactant. An outermost encapsulant is substantially nonreacting, impermeable and nondissolving with water. The reactant(s) contribute to at least one reaction with contaminants in environmental media rendering the environmental media less harmless. Processes for using the encapsulated reactant in environmental media is also hereby claimed.

Abstract: Provided herein are methods and compositions that include a method comprising contacting a metal surface with an acidic fluid comprising a corrosion inhibitor that comprises a reaction product formed from a direct or an indirect reaction of an aldehyde with a thiol and/or an amine functionalized ring structure. A composition provided includes an acidic treatment fluid that comprises an aqueous-base fluid, and acid, and a corrosion inhibitor that comprises a reaction product formed from a direct or an indirect reaction of an aldehyde with a thiol and/or an amine functionalized ring structure.

Abstract: Many methods are presented herein including a method comprising: providing a metal surface; and contacting the metal surface with a treatment fluid comprising an aqueous base fluid, an acid, a corrosion inhibitor, and a corrosion inhibitor intensifier composition comprising a corrosion inhibitor compound that corresponds to a formula: PR1R2R3, wherein R1, R2, and R3 are chosen from the group consisting of C1-C20 alkyl, cycloalkyl, oxyalkyl, and aryl groups, and R1, R2, and R3 may or may not be equal. Corrosion inhibitor intensifier compositions also are provided.

Abstract: Treatment fluids that comprise a phosphorus component useful for inhibiting metal corrosion in acidic environments and associated methods of use are provided. An example of a method of using such treatment fluids may comprise providing a treatment fluid that comprises: an aqueous base fluid, a weak acid or salt thereof, and a phosphorus component, and introducing the treatment fluid into a subterranean formation.

Abstract: A drilling fluid comprising: a non-ionic surfactant including at least one of a branched alcohol ethoxylate and a capped alcohol ethoxylate, a detergent builder and a viscosifier.

Abstract: A microemulsion system is disclosed which comprises a solvent subsystem, a co-solvent subsystem and a surfactant subsystem comprises at least one monoalkyl branched propoxy sulfate anionic surfactant, where the microemulsion system are useful in drilling, producing, remediation, and fracturing application to reduce water blocks and water blocking in formation of a producing formation.

Abstract: Hydrocarbon fluid compositions comprising a liquid hydrocarbon, an aluminum soap, a hydrocarbon foaming agent and a gas. The fluids can be used in various oil field operations.

Abstract: An invert emulsion wellbore fluid comprising an oleaginous continuous phase, an aqueous discontinuous phase, and an emulsifying fluid, wherein the emulsifying fluid comprises an aliphatic alcohol and a glycoside, is disclosed.

Abstract: A method and composition for crosslinking a polymer based fluid includes providing a dry blend of crosslinker and delay agent. The crosslinker and delay agent are mixed and granulated in a dry form prior to addition to the polymer fluid.

Abstract: A method of servicing a wellbore comprising placing a composition comprising a surfactant, brine, an oleaginous fluid, and optionally a co-surfactant in an annular space of the wellbore, wherein the composition forms a microemulsion under low shear conditions.

Abstract: A delayed crosslinker system useful in downhole treatment fluids is disclosed. The crosslinker system comprises water-reactive solids, a non-aqueous, non-oily, hygroscopic liquid, a suspension aid, and an optional polyol. The crosslinker system may be prepared at a remote location and transported to the site of its intended use. There it may be pumped into a formation and activated when a gel fluid is introduced into the wellbore, only then forming a high viscosity treatment fluid. Thus, the amount of energy required for pumping is reduced. The optional polyol component increases crosslink delay and enhances the rate of viscosity after high shear (shear recovery).

Abstract: A composition for treating a portion of a wellbore or a portion of a subterranean formation is provided, the composition comprising: (a) water; (b) a source of hydrogen peroxide, and (c) an activator for the source of hydrogen peroxide; wherein the pH of the composition is adjusted to be within an appropriate range for the type of activator. A method for treating a portion of a wellbore or a portion of a subterranean formation, the method comprising the steps of: forming or providing a composition comprising: (a) water; (b) a source of hydrogen peroxide, and (c) an activator for the source of hydrogen peroxide; wherein the pH of the composition is adjusted within an appropriate range for the type of activator; and introducing the composition through a wellbore to treat a portion of a wellbore or a portion of a subterranean formation. The activator can be a water-soluble alkanoyl-donor compound or a chelated transition metal. Preferably, the composition further comprises an iron chelating agent.

Abstract: A method comprising contacting a zwitterionic surfactant, co-surfactant, and water to form a microemulsifier, and contacting the microemulsifier with an oleaginous fluid under low shear conditions to form a microemulsion. A method comprising introducing a first wellbore servicing fluid comprising at least one oleaginous fluid into a wellbore, wherein the first wellbore servicing fluid forms oil-wet solids and/or oil-wet surfaces in the wellbore, and contacting the oil-wet solids and/or oil-wet surfaces in the wellbore with a second wellbore servicing fluid comprising a zwitterionic surfactant, a co-surfactant, and a brine to form a microemulsion.

Abstract: Methods are provided that include a method comprising providing a acidic treatment fluid that comprises a base fluid, an acid composition, and a gelling agent that comprises clarified diutan; and introducing the acidic treatment fluid into at least a portion of a subterranean formation. In some embodiments, the acidic treatment fluid may be allowed to interact with a component of the subterranean formation so that the component is at least partially dissolved. In some embodiments, the acidic treatment fluid may be introduced into a pipeline. Additional methods are also provided.

Abstract: A method for treating solid materials is disclosed, where the treating compositions coats surfaces or portions of surfaces of the solid materials changing an aggregation or agglomeration propensity of the materials. Treated solid materials are also disclosed. The methods and treated materials are ideally suited for oil field applications.

Abstract: A method for treating a subterranean formation includes forming a treatment fluid including a carrier fluid, a solid acid-precursor, and a solid scale inhibitor. The solid acid-precursor includes a material that forms an acid at downhole conditions in the subterranean formation. The method further includes adding a solid acid-responsive material into the treatment fluid, where the solid acid-responsive material enhances formation of acid from the solid acid-precursor in acidic conditions. The method includes performing an acid fracture treatment and inhibiting scale formation within the subterranean formation. The solid scale inhibitor allows for long-term scale inhibition after the treatment.

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: 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 gelled organic-based fluid system and method of forming and using the system. The fluid system is prepared by gelling an organic solvent, a viscoelastic surfactant, and a nitrogen compound having a free electron pair such as urea in an amount effective to both increase viscosity and increase a rate of breaking the viscosity, relative to the gelled system without the nitrogen compound. In a further aspect, the method is used to treat a well penetrating a subterranean formation, for example, in a coiled tubing cleanout, or the like.

Abstract: A low toxicity composition and method of reducing the swelling of clay in well comprising circulating in the well a water-based fluid comprising a functionally effective concentration of the additive formed from the following reaction of a tertiary amine of the following general formula: wherein R1 and R2 are alkyl or hydroxyalkyl groups with one to three carbon atoms or combinations thereof, and R3 is a hydroxyalkyl group with one to three carbon atoms, with an alkylating agent of the following general formula: R-A wherein R is an alkyl radical with one to three carbon atoms, and A is an organic or inorganic anion selected from the group consisting of sulfate, phosphate, carbonate, and combinations thereof.

Abstract: The invention is directed to methods for treating a portion of a well. The methods include the steps of: (A) forming a viscoelastic treatment fluid, wherein the treatment fluid comprises: (i) water; (ii) a viscoelastic surfactant (“VES”), wherein the VES is soluble in the water and wherein the VES is in the form of micelles; and (iii) a cross-linking agent for the VES molecules, wherein: (a) the cross-linking agent comprises cross-linking agent molecules having at least one complexed transition metal, wherein the transition metal has a valence state of at least three; and (b) the cross-linking agent is soluble in the water; and (B) introducing the treatment fluid into a portion of the well. According to a first aspect of the invention, (a) the VES comprises VES molecules having an alkyl group of greater than 14 carbon atoms and (b) the VES comprises VES molecules having at least one functional group selected from a carboxylate group, an amino group, an alcohol group, and an ether group.

Abstract: A fracturing fluid for a downhole environment is disclosed, comprising a water-sensitive gel; and a hydrated breaker. A fracturing fluid for a downhole environment is also disclosed, the fracturing fluid comprising a water-sensitive carrier and a breaker, the breaker comprising one or more hydrates, and wherein water of the one or more hydrates is releasable so as to act with the water-sensitive carrier to reduce the viscosity of the fluid. A method of treating a downhole environment with a fracturing fluid is also disclosed, the method comprising: providing to the downhole environment a fluid comprising a water-sensitive carrier and a breaker, the breaker comprising one or more hydrates; and allowing water from the one or more hydrates to release so as to act with the carrier to reduce the viscosity of the fluid.

Abstract: An aqueous, foamable composition useful for formation fracturing is disclosed, which includes an ionically coupled gel system. These compositions are well suited in fracturing formation where there are insufficient or non-existent hydration units. Methods for making the compositions and methods using the foamable compositions to fracture formation with insufficient hydration units.

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: Treatment fluids are provided that include a treatment fluid comprising a base fluid and a gelling agent that comprises clarified diutan. In some embodiments, the treatment fluid is a subterranean treatment fluid. In some embodiments, the treatment fluid is a subterranean treatment fluid comprising a base fluid, a gelling agent that comprises clarified diutan, and at least a plurality of particulates. Additional treatment fluids are also provided.

Abstract: A method of servicing a wellbore comprising providing a composition comprising a mutual solvent precursor, an acid precursor, and an aqueous fluid, and contacting the composition with oil wet solids in the wellbore. A method of servicing a wellbore comprising introducing an oil-based fluid into a wellbore, wherein the oil-based fluid forms oil wet solids in the wellbore, contacting the oil wet solids in the wellbore with a composition comprising a mutual solvent precursor; an acid precursor and an aqueous fluid, and allowing the oil wet solids to become water wet. A method of servicing a well bore comprising contacting a composition comprising a formate ester with oil wet solids in the well bore under conditions wherein the formate ester hydrolyzes to release formic acid, wherein the formic acid catalyzes the hydrolysis of additional formate ester, and wherein all or a portion of the formate ester converts at least a portion of the oil-wet solids to water-wet solids.

Abstract: A method of acidizing and cleaning up a formation is disclosed, the formation being above 150 degrees C. The formation is treated with a mutual solvent system comprising a mutual solvent of oil and water, an aqueous acid, a corrosion inhibitor, and an iron control agent. In some embodiments, the iron control agent is present in an amount of less than 1% by weight of the mutual solvent system. In some embodiments, the corrosion inhibitor may be present in an amount of less than 10% by weight of the mutual solvent system. In some embodiments, the mutual solvent system further comprises an intensifier.

Abstract: A well treatment microemulsion for use in a subterranean formation is disclosed, the microemulsion comprises a solvent blend comprising a solvent and a co-solvent; a surfactant blend comprising a surfactant, wherein the surfactant blend is able to give formation intermediate wettability properties; an alcohol; and a carrier fluid; wherein the alcohol, the solvent and surfactant blends are combined with the carrier fluid to produce the well treatment microemulsion. By intermediate wettability it is meant that the water has an advancing contact angle on the surface between 62 and 133 degrees. The associate method of treating a subterranean formation of a well with the microemulsion and the associate method of modifying the wettability of the formation with the microemulsion are also disclosed.

Abstract: The invention relates to polymers with a mean molecular weight of between 500 and 500,000 g/mol that can be produced as follows: A) reaction of a compound of formula 1, in which n stands for 0, 1 or 2 and A for an arbitrarily substituted C1-C40 group with a compound of the formula 2 B(OH)m in which m is from 2 to 10 and B is a represents an arbitrarily substituted C2-C40 group, B) subsequently reaction of the product thus obtained with a nitrogen-containing carboxylic acid which comprises from 1 to 20 carbon atoms, where the molar ratio between the number of free OH groups of the polyester obtained in step A and the nitrogen-containing carboxylic acid is between 1:0.1 and 1:1. The polymers are used to inhibit gas hydrate formation.

Abstract: A microemulsion system is disclosed which comprises a solvent subsystem, a co-solvent subsystem and a surfactant subsystem comprises at least one monoalkyl branched propoxy sulfate anionic surfactant, where the microemulsion system are useful in drilling, producing, remediation, and fracturing application to reduce water blocks and water blocking in formation of a producing formation.

Abstract: Improved methods of placing and/or diverting treatment fluids in subterranean formations are provided. In one embodiment, the methods comprise introducing a treatment fluid into a subterranean formation penetrated by a well bore, wherein the treatment fluid comprises: a base fluid, and a plurality of solid particulates comprising at least one selected from the group consisting of: a scale inhibitor, a chelating agent, and a combination thereof, wherein the solid particulates are substantially insoluble in the base fluid; and allowing at least a portion of the solid particulates to form a barrier or at partially divert a subsequent fluid.

Abstract: An annular fluid or packer fluid, and methods of making the same, that includes a water-miscible solvent, a viscosifying additive, a crosslinking agent, a crosslinking inhibitor having the facility to inhibit crosslinking between the viscosifying additive and the crosslinking agent, and an initiating agent having the facility to overcome an action of the crosslinking inhibitor and to initiate crosslinking between the viscosifying additive and the crosslinking agent, is shown and described. The fluid has a thermal conductivity of no more than about 0.25 btu/(hr·ft·° F.) and a potential to substantially increase its viscosity upon sitting for a selected period of time.

Abstract: A non-aqueous, non-flammable Group IVB metal alkoxide crosslinker composition includes a non-aqueous, non-flammable Group IVB metal alkoxide, wherein the metal is chemically bonded to a glycol containing 4 or more carbons, to an alkoxy group containing 6 or more carbons, or a mixture of both. A fracturing fluid employed in the hydraulic fracturing of subterranean formations is formulated through mixture of the non-aqueous, non-flammable Group IVB metal alkoxide crosslinker composition with a polymer solution.

Abstract: A composition for mitigating or preventing the formation of an emulsion between naphthenic acid and metal cations in a hydrocarbon body, the composition including at least one alkoxylated amine and at least one acid and/or alcohol is disclosed.

Abstract: Embodiments of the present invention are directed to defoaming methods and compositions for well treatment fluids. An exemplary embodiment of the present invention provides a method of defoaming a well treatment fluid, comprising combining a defoaming composition with the well treatment fluid, wherein the defoaming composition comprises an amide of a carboxylic acid, a polypropylene glycol, an ethoxylated and propoxylated fatty alcohol, an ethoxylated alcohol comprising from 3 carbons to 6 carbons, and a hydrophobic silica in an amount of up to about 3% by weight of the defoaming composition.

Abstract: Embodiments of this invention relate to a composition and a method for dissolving a filtercake in a subterranean formation comprising forming a mixture comprising a dissolution fluid and a fluid comprising hydrocarbon; introducing the mixture into a subterranean formation containing a filtercake; introducing an aqueous fluid to the mixture; and dissolving the filtercake. Embodiments of this invention also relate to further exposing the mixture to swellable packer. Embodiments of this invention relate to a method for a composition, comprising a fluid comprising hydrocarbon; and a dissolution fluid, wherein the fluid comprising hydrocarbon and dissolution fluid are combined to form a miscible mixture that dissolves a filtercake in a subterranean formation.

Abstract: A method of creating a carbon dioxide hydrate is disclosed. The preferred steps include supplying liquid carbon dioxide and a dissociation agent to a hydrocarbon hydrate, decomposing the hydrocarbon hydrate by the dissociation agent into a hydrocarbon gas and liquid water, and forming the carbon dioxide hydrate from the liquid carbon dioxide and the liquid water. The dissociation agent preferably is at least one of an inorganic salt, a surface active agent, a hydrate inhibitor, and an absorption solution. Furthermore, a substance composition of liquid carbon dioxide and the dissociation agent is described, which is provided for depositing carbon dioxide hydrate in a subterranean geological formation. Furthermore, a deposition device is described, which is configured for depositing carbon dioxide hydrate in a subterranean geological formation.

Abstract: Dual-function nano-sized particles or nanoparticles may be effective at fixating or reducing fines migration and they may facilitate identification of a particular zone in a well having more than one zone. In some embodiments the dual-function nanoparticles are tagged with a detectable material that is distinguishable from the composition of the primary nanoparticle component. In these embodiments, the taggant material rather than the primary component of the nanoparticles may be used to enable identification of a particular zone. The nanoparticles (with or without taggant) may be added to a treatment fluid containing carrier particles such as proppant. The treatment fluid is pumped downhole to one of the zones; each zone receiving its own unique or uniquely-tagged nanoparticles. Should one of the zones fail, the composition of the nanoparticles (or its taggant) produced on the carrier particles may be correlated to the zone from which it was received, and hence produced.