Abstract: In a method of gravel packing a wellbore in a subterranean formation, the wellbore comprising a cased section and an uncased section, the method may include pumping into the wellbore a gravel pack composition comprising gravel and a carrier fluid comprising an invert emulsion fluid, where the invert emulsion fluid may comprise: an oleaginous external phase; a non-oleaginous internal phase, wherein a ratio of the oleaginous external phase and non-oleaginous internal phase is less than 50:50 and an emulsifier stabilizing the oleaginous external phase and the non-oleaginous internal phase.

Abstract: A system and method are disclosed for low damage gravel packing. The system comprises a well bore; a gravel packing slurry comprising a carrier fluid and a solids mixture, wherein the solids mixture comprises a plurality of volume-averaged particle size distribution (PSD) modes such that a packed volume fraction (PVF) exceeds 0.75, wherein the solids mixture comprises at least a proppant PSD mode and a fines PSD mode; a pump to circulate the slurry in the wellbore and form a proppant pack; and a dispersant source effective to facilitate fines flowback from the pack. The method comprises circulating the slurry through a wellbore to form a proppant pack; contacting fines in the pack with a dispersant; and passing fluid through the pack to remove fines from the pack.

Abstract: High solids content slurry, systems and methods. The slurry comprises a carrier fluid and a solids mixture of first, second, third and fourth particle size distribution (PSD) modes wherein the first PSD mode is at least three times larger than the second PSD mode, which is larger than the third PSD mode, which is larger than the fourth PSD mode, and wherein at least one of the second and third PSD modes is less than 3 times larger than the respective third or fourth PSD mode. The method comprises forming the slurry, positioning a screen in a wellbore and circulating the slurry through the wellbore such that the solids mixture is deposited between the screen and the wellbore. The system comprises a pump to circulate the slurry, a workstring to position the screen and means for converting the slurry to a gravel pack.

Abstract: A method and system are disclosed for low damage gravel packing. The method comprises: combining a carrier fluid and a solids mixture into a slurry, wherein the solids mixture comprises a plurality of particle size distribution modes such that a packed volume fraction exceeds 0.75; contacting a screen with leak-off control agent to form a bridge; positioning the screen and circulating the slurry through the wellbore in any order such that the solids mixture is deposited between the screen and the wellbore; degrading the degradable material to increase porosity and permeability of the pack; removing the bridge; and producing a reservoir fluid from the formation. The system comprises the slurry, a tubing string and slurry pump to position the screen and circulate the slurry to form the bridge on the screen.

Abstract: A composition and method are disclosed. The composition includes a carrier fluid and a solids mixture combined to form a slurry, wherein the solids mixture comprises a plurality of volume-averaged particle size distribution (PSD) modes, wherein a first PSD mode comprises solids having a volume-average median size at least three times larger than the volume-average median size of a second PSD mode such that a packed volume fraction of the solids mixture exceeds 0.75, and wherein the solids mixture comprises a degradable material and includes a reactive solid. The method includes circulating the slurry through a wellbore to form a pack in a fracture and/or a screen-wellbore annulus; degrading the degradable material to increase porosity and permeability of the pack; and producing a reservoir fluid through the permeable pack.

Abstract: A method comprises providing a treatment fluid having a first viscosity comprising an aqueous base fluid; a viscoelastic surfactant; and a stimuli-responsive water-soluble polymer; introducing the treatment fluid into a subterranean formation; and allowing the treatment fluid viscosity to change to a second viscosity in response to a stimulus.

Abstract: Water-based drilling mud lubricants using a blend of fatty acid polyamine salts and fatty acid esters give synergistically better lubricity results than either component used separately. For example, the blends with different ratios of fatty acid diethylenetriamine salt and fatty acid methyl ester demonstrate much better lubricity in water-based drilling fluids than those where only fatty acid diethylenetriamine salt or fatty acid methyl ester are separately used. The amines in fatty acid amine salt might also include other polyamines, such as butanediamine pentamethylenediamine, spermidine, spermine, propylene diamine and propylene polyamines. The fatty acid esters might also include fatty acid ethyl ester, fatty acid glycerol ester and fatty acid trimethylolpropane ester. The carbon numbers of the fatty acids used to make the components in the lubricant blend may range from C4 to C28.

Abstract: Viscoelastic compositions are disclosed herein containing an effective amount of one or more random or structurally defined polycationic quaternary ammonium compounds for controlling the viscoelasticity of the composition. In one aspect, the present technology provides polycationic quaternary ammonium compounds that comprise bis-quaternary compound. The bis-quaternary compounds of the present technology can be symmetric or dissymmetric. In another aspect, the present technology provides viscoelastic well bore treatment fluids comprising water, and at least one polycationic quaternary ammonium compound that comprises a bis-quaternary compound. In another aspect, the present technology provides polycationic carboxylates. Preferred viscoelastic compositions of the present technology maintain viscoelasticity at a temperature greater than about 80° C., preferably greater than about 100° C. or 110° C.

Abstract: Methods of forming gravel packs while reducing fluid loss to the surrounding subterranean formation. The methods involve suspending gravel that has been coated with a tackifying agent and degradable fines into a low viscosity carrier fluid and then placing that suspension into a subterranean formation so as to form a gravel pack wherein, as the gravel pack is placed, the degradable fines to de-adhere from the gravel and to fill at least a portion of the pore spaces within the gravel pack so as to reducing fluid loss through the gravel pack.

Abstract: A method and apparatus for fracturing a formation containing a wellbore comprising the steps of (a) injecting a gel into the wellbore; (b) permitting the gel to increase in viscosity and (c) fracturing the formation in the vicinity of the gel.

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

Abstract: Viscoelastic compositions are disclosed herein containing an effective amount of one or more random or structurally defined polycationic quaternary ammonium compounds for controlling the viscoelasticity of the composition. In at least one aspect, the present technology provides polycationic quaternary ammonium compounds comprising dissymmetric bis-quaternary compounds. In another aspect, the present technology provides viscoelastic compositions comprising polycationic quaternary ammonium compounds that comprise dissymmetric bis-quaternary compounds. In yet another aspect, the present technology provides polycationic quaternary ammonium compounds comprising a carboxylate functional polycationic quaternary ammonium compound. Preferred viscoelastic compositions of the present technology maintain viscoelasticity at a temperature greater than about 80° C., preferably greater than about 100° C. or about 110° C.

Abstract: Subterranean treatment fluids that exhibit enhanced particulate transport or suspension capabilities, and associated methods of use in certain subterranean treatments are provided. In one embodiment, the methods comprise: providing a linear gelled fluid that comprises an aqueous base fluid, a plurality of particulates, and a linear particulate transport enhancing additive, the linear gelled fluid having a certain yield stress, crossover frequency, and/or particulate settling time; introducing the linear gelled fluid into the subterranean formation; and using the linear gelled fluid to create or enhance at least one fracture in at least a portion of the subterranean formation.

Abstract: Viscoelastic compositions are disclosed herein containing an effective amount of one or more random or structurally defined polycationic quaternary ammonium compounds for controlling the viscoelasticity of the composition. In at least one aspect, the present technology provides polycationic quaternary ammonium compounds comprising bis-quaternary compounds. In another aspect, the present technology provides viscoelastic compositions that comprise polycationic quaternary ammonium compounds comprising bis-quaternary compounds. Preferred viscoelastic compositions of the present technology maintain viscoelasticity at a temperature greater than about 80° C., preferably greater than about 100° C. or about 110° C. when the amount of the one or polycationic quaternary compounds is less than about 10% by weight based on the total weight of the composition.

Abstract: Viscoelastic compositions are disclosed herein containing an effective amount of one or more random or structurally defined polycationic quaternary ammonium compounds for controlling the viscoelasticity of the composition. In one aspect, the present technology provides polycationic quaternary ammonium compounds that comprise bis-quaternary compound. The bis-quaternary compounds of the present technology can be symmetric or dissymmetric. In another aspect, the present technology provides viscoelastic well bore treatment fluids comprising water, and at least one polycationic quaternary ammonium compound that comprises a bis-quaternary compound. In another aspect, the present technology provides polycationic carboxylates. Preferred viscoelastic compositions of the present technology maintain viscoelasticity at a temperature greater than about 80° C., preferably greater than about 100° C. or 110° C.

Abstract: A gravel packing fluid and method for gravel packing a wellbore using a gravel packing fluid comprising an invert emulsion comprising oil as an external phase, clear brine as an internal phase, and a quantity of emulsifier effective to produce a stable invert emulsion, the external phase of the gravel packing fluid further comprising gravel wetting agent.

Abstract: A method is disclosed for low damage gravel packing. The method includes combining a carrier fluid, a first amount of particulates, and a second amount of particulates into a slurry. The first amount of particulates have a first average size distribution and the second amount of particulates have a second average size distribution, and the first average size distribution is at least three times larger than the second average size distribution. The slurry includes particles which are at least partially degradable material, and with reactive solid constituents. The reactive solid reacts with the degradable material and/or a hydrolysis product of the degradable material. The method further includes positioning a screen in a wellbore, and circulating the slurry through the wellbore such that the first amount of particulates and the second amount of particulates are deposited on an outer surface of the screen.

Abstract: Viscoelastic compositions are disclosed herein containing an effective amount of one or more random or structurally defined polycationic quaternary ammonium compounds for controlling the viscoelasticity of the composition. In at least one aspect, the present technology provides polycationic quaternary ammonium compounds comprising dissymmetric bis-quaternary compounds. In another aspect, the present technology provides viscoelastic compositions comprising polycationic quaternary ammonium compounds that comprise dissymmetric bis-quaternary compounds. In yet another aspect, the present technology provides polycationic quaternary ammonium compounds comprising a carboxylate functional polycationic quaternary ammonium compound. Preferred viscoelastic compositions of the present technology maintain viscoelasticity at a temperature greater than about 80° C., preferably greater than about 100° C. or about 110° C.

Abstract: The present invention relates to the use of chalcogen heterocyclic electron donating compounds as thermal decomposition reduction additives for gels used in well treatment fluids such as drilling fluids, fracturing fluids, and well completion and workover fluids.

Abstract: Degradable polylactic or polyhydroxyalkanoate polymers may be used to viscosify aqueous fluids for use in wells. Sand control screen or liner can be coated with a solid degradable polymer during placement in a well. Mechanical changes or flow changes in a well can be caused by solid degradable polymer that changes physical properties after it is placed in a well. Parts of devices or entire devices can be made of solid degradable polymer that converts to a fluid after selected times in an aqueous environment in a well.

Abstract: An efficient oil based drilling fluid is provided that includes a polymer additive effective at imparting suspension characteristics without the presence of organophilic clays, while also providing filtration control. The fluid is shear thinning and has good fluid rheology over a broad temperature range. A preferred polymer for the additive is substantially linear and comprises mostly hydrophobic monomers and some hydrophilic monomers such as, for example, an emulsion copolymer of 2-ethylhexyl acrylate and acrylic acid.

Abstract: The present invention relates to the use of chalcogen heterocyclic electron donating compounds as thermal decomposition reduction additives for gels used in well treatment fluids such as drilling fluids, fracturing fluids, and well completion and workover fluids.

Abstract: Provided are methods of modifying the stress-activated reactivity of subterranean fracture faces and other surfaces in subterranean formations. In one embodiment, the methods comprise: providing a treatment fluid that comprises a base fluid and a surface-treating reagent capable of modifying the stress-activated reactivity of a mineral surface in a subterranean formation; introducing the treatment fluid into a subterranean formation; and allowing the surface-treating reagent to modify the stress-activated reactivity of at least a portion of a mineral surface in the subterranean formation.

Abstract: An inhibitive water-based polymer mud system and method for using the system in drilling and in stabilizing wellbores is disclosed for use in water sensitive formations as an alternative to oil-based muds. The system comprises a non-ionic low molecular weight polyacrylamide in combination with a non-ionic high molecular weight polyacrylamide, preferably long chain alcohol and poly anionic cellulose.

Abstract: A sealant composition and methods for using the same are disclosed. In an embodiment, a method of servicing a wellbore in contact with a subterranean formation is disclosed. The method comprises placing a sealing agent and a nonaqueous carrier fluid in the wellbore. The method further comprises placing a nonaqueous activating fluid in the wellbore. In addition, the method comprises contacting the sealing agent with the nonaqueous activating fluid to form a sealant composition.

Abstract: Methods of enhancing at least partially the structural integrity of a longitudinal portion of a deviated well bore are provided. The methods include providing a gravel matrix composition; providing a longitudinal portion of a deviated well bore; and placing a sufficient amount of the gravel matrix composition in the longitudinal portion to enhance the structural support of the longitudinal portion. Optional additives may include curable resins, tackifiers, and/or the incorporation of a degradable material in the gravel matrix composition.

Abstract: A well treating composition containing a polysaccharide-based water-superabsorbent material has particularly applicability as a thermal insulating, fracturing or acid stimulation fluid. The water-superabsorbent material is capable of absorbing, at a minimum, its own weight. Particularly effective are biodegradable materials containing guar gum and carrageenan. The composition may further contain a crosslinking agent, brine and/or a viscosifying polymer or a gelling agent. As an oil-based fluid, the crosslinking agent is absorbed onto the water-superabsorbent material and serves to effectively delay crosslinking.

Abstract: Fluids, such as completion fluids, containing at least one alkali metal tungstate and optionally at least one chelating agent are described. Methods of removing a filter cake from a well bore surface, which may include one or more alkaline earth metal sulfates, is also described, wherein the method includes contacting the filter cake with the completion fluid of the present invention. A drilling fluid or mud is also described wherein the drilling fluid contains at least one alkali metal tungstate. The drilling fluid preferably further contains at least one emulsifier or surfactant and at least one hydrocarbon-based fluid. The various fluids of the present invention can contain other conventional ingredients and optionally at least one alkali metal formate. The present invention permits the fluids to be essentially solids free due to the use of the alkali metal tungstate.

Abstract: A temperature-stable, non eco-toxic oil-base well fluid that is particularly suitable for high pressure/high temperature drilling comprises an emulsification system comprising at least one superamide that may or may not be polyalkoxylated, optionally associated with a non-ionic co-surfactant. The oil-base well fluid comprising such a system can be used at temperatures of up to about 200° C. due to the production of highly temperature-stable reverse emulsions.

Abstract: An aqueous-based composition containing cesium formate and at least one chelating agent is described. Methods of removing scaling deposits, which may include alkaline earth metal sulfates, present on surfaces, including porous media, such as alkaline earth metal sulfate buildup in a well bore, is also described, wherein the method includes contacting the alkaline earth metal sulfate with the compositions of the present invention to remove the scaling deposits. A completion fluid containing at least one alkali metal formate, at least one acid and/or at least one chelating agent, and optionally at least one surfactant or mutual solvent is also described. Methods of removing a filter cake from a well bore surface, which may include weighting agents such as calcium carbonate, is also described, wherein the method includes contacting the filter cake with the completion fluid of the present invention.

Abstract: Improved well fluids that include hollow particles, and methods of using such improved well fluids in subterranean cementing operations are provided. Also provided are methods of cementing, methods of reducing annular pressure, and well fluid compositions. While the compositions and methods of the present invention are useful in a variety of subterranean applications, they may be particularly useful in deepwater offshore cementing operations.

Abstract: The present invention relates to servicing fluids for use in subterranean operations. More particularly, the present invention relates to improved servicing fluids comprising optimized hydrocarbon blends and methods of using such servicing fluids in subterranean formations. One embodiment of the preset invention provides a method of treating a subterranean formation comprising the steps of providing a servicing fluid comprising a hydrocarbon blend wherein the hydrocarbon blend comprises at least about 65% hydrocarbons having from 6 carbons (C6) to eleven carbons (C11); and placing the servicing fluid into the subterranean formation. Another embodiment of the present invention provides a subterranean servicing fluid comprising a hydrocarbon blend wherein the hydrocarbon blend comprises at least about 65% hydrocarbons having from 6 carbons (C6) to eleven carbons (C11).

Abstract: Methods and compositions for wellbore treating fluids, especially settable spotting fluids, that include zeolite and at least one carrier fluid.

Abstract: Methods and compositions for wellbore treating fluids, especially remedial compositions such as pills, that include zeolite and at least one carrier fluid.

Abstract: Foamed completion fluids and methods of completing subterranean zones penetrated by well bores are disclosed. A method of completing a subterranean zone penetrated by a well bore comprises the steps of providing or preparing a foamed completion fluid comprising water, one or more salts, a gas and a capryl/capramidopropylbetaine surfactant foaming agent, introducing the foamed treating fluid into the subterranean zone, and then carrying out a completion operation in the subterranean zone.

Abstract: The present invention provides variable density fluid compositions and methods for using such compositions in a subterranean formation. One exemplary embodiment of the variable density fluid compositions of the present invention comprises a variable density fluid comprising: a base fluid, and a portion of variable pressure weighting material particles.

Abstract: The present invention relates to improved well fluids that include hollow particles, and to methods of using such improved well fluids in subterranean cementing operations. The present invention provides methods of cementing, methods of reducing annular pressure, and well fluid compositions. While the compositions and methods of the present invention are useful in a variety of subterranean applications, they may be particularly useful in deepwater offshore cementing operations.

Abstract: The current invention provides improved methods and compositions for completing a well bore. In one aspect, the current invention provides a process for preparing a foamed well composition. The process utilizes air to foam the composition after the air has been treated to lower the oxygen content below that concentration necessary to support combustion. Additionally, the current invention provides a process for completing and/or treating a well bore using a foamed composition wherein the foam is generated with reduced oxygen content air. Finally, a preferred embodiment of the invention provides a foamed cement composition wherein the gaseous portion of the composition is air having a reduced oxygen content.

Abstract: A method is disclosed for reducing sag in drilling and completion fluids and in workover fluids. The method employs a drilling fluid comprising a low molecular weight polyalkyl methacrylate with an average molecular weight ranging from about 40,000 to about 90,000. This additive does not result in significantly increased viscosity of the fluid.

Abstract: A system and method for removing particles from a well bore penetrating a possible hydrocarbon producing formation, according to which drilling fluid is mixed with a weighted material, and the mixture is introduced into a well bore so that the mixture scours any particles accumulated in the well bore. A well-completion fluid is introduced into the well bore that dissolves the weighted material.

Abstract: A method for producing a precursor polymer dispersion for addition to a brine for use in drilling and completion operations comprising providing a precursor brine having a first salt content, and mixing a water-soluble polymer with the precursor brine at a sufficient concentration and under conditions sufficient to produce a precursor polymer dispersion effective at a sufficient concentration in a final brine having a second salt content to improve the rheology and/or fluid loss control properties of the final brine.

Abstract: A method is disclosed for reducing sag in drilling and completion fluids and in workover fluids. The method employs a drilling fluid comprising a low molecular weight polyalkyl methacrylate with an average molecular weight ranging from about 40,000 to about 90,000. This additive does not result in increased viscosity of the fluid.

Abstract: Liquid water soluble polymer suspensions in non-aqueous solvents are extremely stable over long periods of time with minimum separation of the solvent and no hard packing of the dispersed water soluble polymer. The suspensions enable a user to rapidly add the suspension to water, being mixed at low speeds, without the formation of lumps or fisheyes and without generating fugitive dust in the process. The suspensions are environmentally safe and biodegradable. Unlike many other liquid polymer suspensions, the suspensions exhibit minimal oil or grease upon dilution. They contain no surfactants that can add to the oil and grease determination. The suspensions and the fluids produced by diluting the fluids to a working concentration of the water soluble polymer exhibit low toxicity to marine organisms and to humans. The suspensions can be manufactured from ingredients suitable for use in personal care applications such as cosmetics, shampoos and the like.

Abstract: The present invention provides xanthan gels hydratable in brine, methods of making these xanthan gels, and methods of using these compositions in subterranean formation applications, such as gravel packing.

Abstract: Invert emulsion compositions including an oleaginous, a non-oleaginous and an amine surfactant that are useful in the oil and gas well drilling art are disclosed. The amine surfactant is selected so that the invert emulsion can be converted form a water-in-oil type emulsion to a oil-in-water type emulsion upon the protonation of the amine surfactant. Deprotonation of the amine surfactant reverses the conversion.

Abstract: A wellbore fluid having a non-aqueous continuous liquid phase that exhibits an electrical conductivity increased by a factor in order of 104 to 107 compared to conventional invert emulsion comprises from about 0.2% to about 10% by volume of carbon black particles and one or more emulsifying surfactant(s) selected from the class including nonionic emulsifiers of Hydrophilic-Lipophilic Balance (HLB) less than about 12, and anionic surfactants wherein the counter-ion (cation) is any of alkali metal, ammonium, or hydrogen ions. This wellbore fluid can be used for drilling or completing a well and can be used for providing enhanced information from electrical logging tools, measurement while drilling, logging while drilling, geosteering and the like.

Abstract: The present invention generally relates to compositions of matter and methods of using those compositions. More particularly, and as part of one of the preferred embodiments, the present invention relates to compositions and methods of use of fluids useful for sealing formation fractures and/or inhibiting downhole fluid loss. The present invention is useful as a pill or series of pills that can be formulated and spotted to a particular formation zone.

Abstract: The present invention relates to a wellbore fluid comprising a particulate material composed of the reaction product of A) one or more water soluble organic compound having possessing a molecular weight of less than 30,000 and possessing at least two hydroxyl groups and B) any other organic compound(s) capable of forming acetal or hemiacetal cross-links with the hydroxyl groups of compound A. The invention relates also to the specific particulate material itself and to applications of the wellbore fluid of the invention for well processes such as drilling, under-reaming, completing, working over, sealing loss zones, sealing fractures, sealing cavities or other very high permeability conduits in a rock formation, or hydraulic fracturing to stimulate a hydrocarbon-producing zone.

Abstract: A method for removing filter cake from a subterranean borehole comprising drilling the borehole with a drilling fluid that includes additives to form a filter cake having an oxidation-degradable component, preferably a polysaccharide. The filter cake is contacted with a clear brine containing a mixture of a persulfate salt in a variable density brine to degrade the polymers within the filter cake. The persulfate mixture breaks down the filter cake in well bores having temperatures ranging from about 65° F. to 165° F. Concentration of the persulfate sets the pace of the reaction.