Abstract: Drilling fluid additive compositions are provided for use with synthetic, oil based, or water based drilling fluids. The combined additive and drilling fluid are effective for reducing lost circulation, seepage loss as well as wellbore strengthening and/or wellbore lining. The method includes injecting the drilling fluid and 0.01 or more pounds per barrel of a loss control additive including ground and sized pumice, barite or dolomite.

Abstract: Drilling fluid additive compositions are provided for use with synthetic, oil based, or water based drilling fluids. The combined additive and drilling fluid are effective for reducing lost circulation, seepage loss as well as wellbore strengthening and/or wellbore lining. The method includes injecting the drilling fluid and 0.01 or more pounds per barrel of a loss control additive including ground and sized pumice, barite, anthracite or dolomite.

Abstract: A wellbore fluid that includes an oleagninous continuous phase; a non-oleaginous phase; and a polymeric additive formed by reaction of at least one lipophilic epoxy modifier and at least one epoxide-reactive agent, wherein the at least one epoxide-reactive agent comprises at least one selected from lignins, tannins, biopolymers, starches, carboxy methyl cellulose, polyacrylates, polyacrylamides, and synthetic polymers is disclosed.

Abstract: Single phase microemulsions improve the removal of filter cakes formed during drilling with oil-based muds (OBMs). The single phase microemulsion removes oil and solids from the deposited filter cake. Optionally, an acid capable of solubilizing the filter cake bridging particles may also be used with the microemulsion. In one non-limiting embodiment the acid may be a polyamino carboxylic acid. Skin damage removal from internal and external filter cake deposition can be reduced. In another optional embodiment, the single phase microemulsion may contain a filtration control additive for delaying the filter cake removal, destruction or conversion.

Abstract: An invert emulsion wellbore fluid, including: a continuous oleaginous phase; a discontinuous non-oleaginous phase; a stabilizing agent; an oil-immiscible epoxy-based resin; and a hardening agent; wherein the wellbore fluid is a stable emulsion having a viscosity greater than 200 cps. In some embodiments, the hardening agent is an oil-miscible hardening agent; in other embodiments, the hardening agent is an oil-immiscible hardening agent.

Abstract: A drilling fluid has a redispersible polymer powder introduced as a water dispersion that is capable of providing a deformable latex film on at least a portion of a subterranean sand formation and which inhibits or controls fluid loss and acts as a sealing agent when used to drill in sand formations for hydrocarbon recovery operations. The redispersible polymer powder may be made by drying the emulsion in which they are formed and then grinding into a powder or by spray drying. The polymer particles of suitable size precipitate or collect or assemble onto the pores of a subterranean sand formation to at least partial seal the formation with a deformable polymer film.

Abstract: The invention relates to the use of pre-engineered pills for use with drilling mud. By introducing pills of ground elastomer into the well, the pills can improve the lubricity of the mud as well as aiding in wellbore cleaning, prevention of bit balling and reduction of fluid loss to thief zones.

Abstract: Treatments fluids relating to the hydrolysis of water-hydrolysable materials are provided. In one embodiment, provided is a treatment fluid that comprises an aqueous liquid, a water-miscible solvent, and a water-hydrolysable material. Also provided is a hydrolysis retarder composition that comprises an aqueous liquid and a water-miscible solvent.

Abstract: The present invention provides a drilling fluid composition and a method of drilling comprising a drilling fluid, which may be oil- or water-based, and a composite microsphere component. The invention drilling fluid composition advantageously reduces the density of a conventional fluid, reduces costs associated with pumping and overcomes problems associated with conventional gas-injection processes. The invention uses conventional drilling and pumping equipment, requires no sea-floor based pumps and may be easily pressure-controlled to maintain the pressure of the fluid.

Abstract: Herein provided are 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 elastic particles, the elastic particles having an isothermal compressibility factor in the range of from about 1.5×10?3 (1/psi) to about 1.5×10?9 (1/psi). Also provided are cement compositions comprising elastic particles, processes for preparing such cement compositions, and methods of cementing in subterranean formations using such cement compositions. One or more elastic particles are mixed with the cement before pumping the cement into a well bore. The elastic particles are preferably composed of an elastomeric material such as a copolymer of methylmethacrylate and acrylonitrile; a terpolymer of methylmethacrylate, acrylonitrile, and dichloroethane; a styrene-divinylbenzene copolymer; and polystyrene.

Abstract: Latex additives, methods for treating latex additives, drilling fluid systems, and lost circulation pills comprising the latex additives, the latex additive comprising latex particles having a particle size distribution before aging comprising an average particle diameter of about 1 micron or less; and a quantity of one or more water soluble oxygenated organic molecules comprising two or more oxygen atoms effective to maintain substantially the same particle size distribution before and after freezing the latex additive.

Abstract: A region of a borehole with one or more openings to be sealed off, such as one or more fractures, voids, and or pores, may or may not be sealed off around a tubular string with a borehole seal such as a packer or plug. A carrying fluid may be utilized to transport a filtration material into the opening to create a bridge, which at least partially seals the opening, but still provides a flow path that permits fluid flow therethrough. A solid material and/or settable material may then utilize the fluid flow subsequently or be simultaneously spotted with or behind the filtration material to thereby form compositions which effectively seals off the flow path into the one or more openings.

Abstract: An engineered composition for reducing lost circulation in a well includes a mixture of coarse, medium and optional fine particles, and a blend of long fibers and short fibers. The long fibers are rigid and the short fibers are flexible. The long fibers form a tridimensional mat or net in the lost-circulation pathway that traps the mixture of particles and short flexible fibers to form a mudcake. The mixture of particles and blend of fibers may be added to water-based and oil-based drilling fluids. The composition, size, and concentration of each component of the mixture of particles and blend of fibers may be fine-tuned for each application.

Abstract: Embodiments disclosed herein related to an aqueous based well bore fluid that includes at least one ionized polymer, at least one non-ionic polymer, a non-magnetic weighting agent, and an aqueous base fluid.

Abstract: A water-based drilling fluid containing Mn3O4 has been found to be effective in providing petroleum reservoirs with the ability to flow naturally and achieve a return permeability of 90% or greater without the need for acidizing treatments.

Abstract: Thickener systems which are suitable for preparing thickener compositions, and which systems consists of (A) at least one anionic surfactant A and (B) at least one polymer B comprising at least one hydrophobic group and preferably at least one hydrophilic group, wherein the concentration of the polymer B in a thickener composition is below the overlap concentration c* of the polymer, along with processes for preparing such compositions and uses thereof.

Abstract: There is provided a wellbore fluid having a continuous aqueous phase, and comprising at least one polymer which:—has a molecular weight in the range of from 2,000 to less than 100,000; contains hydrophilic units such that the polymer is at least 2% soluble in water at 20° C., and such that less than 50% by weight of said hydrophilic units comprise —CH2—CH2O— units; and contains pendant alkyl groups having at least 10 carbon atoms, the combined molecular weight of said pendant alkyl groups being in the range of from 15 to 70% by weight based on the weight of the polymer. Such aqueous based wellbore fluids exhibit significantly improved fluid loss properties when used in wellbore operations, such as drilling, completion or workover.

Abstract: A composition is comprised of a mixture of the reaction product of an amine and a poly-functional isocyanate, and the reaction product of (i) a carboxylic acid with at least two carboxylic moieties; (ii) a polyamine having an amine functionality of two or more; and a chemical selected from the group consisting of (i) alkoxylated alkyl amines, (ii) fatty acid amides and (iii) mixtures thereof, and it is used as a drilling fluid additive.

Abstract: A composition for wellbore consolidation, comprising fibres having a core formed from a material that is electrically and/or magnetically susceptible, and a polymeric coating, characterised in that when the composition is placed in a wellbore in a zone to be consolidated and an electric current or magnetic field is applied, the fibres bond together by melting or setting of the polymeric coating.

Abstract: Thermoset polymer particles are used in many applications requiring lightweight particles possessing high stiffness, strength, temperature resistance, and/or resistance to aggressive environments. The present invention relates to the use of two different methods, either each by itself or in combination, to enhance the stiffness, strength, maximum possible use temperature, and environmental resistance of such particles. One method is the application of post-polymerization process steps (and especially heat treatment) to advance the curing reaction and to thus obtain a more densely crosslinked polymer network. In general, its main benefits are the enhancement of the maximum possible use temperature and the environmental resistance. The other method is the incorporation of nanofillers, resulting in a heterogeneous “nanocomposite” morphology. In general, its main benefits are increased stiffness and strength.

Abstract: A method of formulating a wellbore fluid that includes grinding a solid particulate material and a polymeric dispersing agent to provide a resulting polymer coated solid material, and suspending the resulting polymer coated solid material in the wellbore fluid. At least a portion of the resulting polymer coated solid material has a particle diameter less than 2.0 microns, wherein the polymeric dispersing agent has a molecular weight greater than 10,000. Exemplary starting materials for the solid material include weighting agents including barite, calcium carbonate, dolomite, ilmenite, hematite or other iron ores, olivine, siderite and strontium sulfate as well as mixture and combinations of these and other similar weighting materials. The dispersant in one illustrative embodiment is a polymeric acrylate ester made from the monomers of stearyl methacrylate, butyacrylate, and acrylic acid.

Abstract: Methods and compositions including a method comprising: providing a treatment fluid comprising a carrier fluid and a solid particle comprising a crosslinked aliphatic polyester; and placing the treatment fluid into a subterranean formation.

Abstract: There is provided a wellbore fluid having a continuous aqueous phase, and comprising at least one polymer which contains both hydrophilic units and hydrophobic units, at least some of said hydrophilic units containing sulfonate groups, and less than 50% by weight of said hydrophilic units comprising —CH2.CH2.O— units; and at least some of said hydrophobic units containing pendant alkyl groups having at least 8 carbon atoms. Such aqueous based wellbore fluids exhibit significantly improved fluid loss properties when used in wellbore operations, such as drilling, completion or workover.

Abstract: Clay is stabilized in the drilling of wells and other formation treatment for hydrocarbon production by the addition to the drilling or other fluid of potassium formate together with a cationic formation control additive.

Abstract: A high temperature well treatment fluid comprising an electron donating compound comprising phenothiazine as thermal decomposition reduction additives for gels used in well treatment fluids is provided. The electron donating compound comprising phenothiazine performs as a stabilizer in well treatment fluids at temperatures of up to about 500° F. (260° C.). Methods of treating wells having subterranean formation temperatures of up to about 500° F. (260 ° C.) using such high temperature well treatment fluids are provided.

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 invention provides a method for the treatment of a hydrocarbon well which method comprises administering, down said well, polymeric particles having covalently bound to a polymeric component thereof a well treatment chemical or a precursor thereof, wherein the particles contain covalent bonds scissile in an aqueous environment to release or expose said chemical or precursor.

Abstract: Methods of controlling shale swelling in a subterranean formation comprising introducing a treatment fluid into the subterranean formation, wherein the treatment fluid comprises a base fluid and a polyoxazoline composition. Subterranean treatment fluids comprising a base fluid and a polyoxazoline composition. Other methods and compositions are also provided.

Abstract: Hydration of clays and shales may be inhibited during drilling operations by using a clay and shale inhibitor. The inhibitor may be used with a water based drilling fluid. The clay and shale inhibitor includes from 0.2 to 5 % by weight of a reaction product of an epoxy resin with at least one primary or secondary aliphatic or cycloaliphatic amine.

Abstract: A method and product is disclosed which provides emulsion stability and filtration control to invert emulsion drilling fluids. The product comprises a blend of a carboxylic acid terminated polyamide with distilled and processed tall oil fatty acids and/or distilled and processed tall oil resin acids. The product is extremely effective, even at temperatures as high as 350° F., decreasing by about two-thirds the amount of emulsifier generally required to formulate an effective drilling fluid. The product also greatly reduces and in many cases eliminates the need for conventional fluid loss additives, and additionally provides electrical stability. Moreover, the product has a pour point as low as about 20 degrees Fahrenheit with minimal solvents, thereby eliminating the need to ship large amounts of inert material for use, and may be transported in a highly active state.

Abstract: The present invention relates to improved methods for drilling well bores penetrating producing zones while controlling formation particulates.

Abstract: A compressible object is described that may be utilized in drilling mud and with a drilling system to manage the density of the drilling mud. The compressible object includes a shell that encloses an interior region. Also, the compressible object has an internal pressure (i) greater than about 200 pounds per square inch at atmospheric pressure and (ii) selected for a predetermined external pressure, wherein external pressures that exceed the internal pressure reduce the volume of the compressible object and wherein the shell being designed to reduce localized strains of the compressible object during expansion and compression of the compressible object.

Abstract: A viscosifying agent for wellbore fluids is described including a polymer polymerized using at least two pre-polymers “A” and “B”, the polymer being capable of essentially fully degrading into soluble fragments after the initiation of a breaking process.

Abstract: The invention concerns an organic composition comprising glycerol polycarbonates, mixed with polyglycerols, [(a-hydroxymethyl)oxyethylene/(a-hydroxymethyl ethylene carbonate) copolymers; optionally [(a-alkyl)oxyethylene/(a-alkyl) ethylene carbonate] copolymers, optionally [(a-alkyl)oxyethylene/(a-hydroxyalkyl)oxyethylene] copolymers, glycerol carbonate and/or other organic carbonates, glycerol and/or other co-produced and/or residual compounds and a method for producing said composition. The inventive composition or the homopolymers and copolymers constituting same, are applicable in the technical fields of hydraulic fluids, lubrication, wood treatment and decoration, fire-retardant treatment, detergency, oil prospecting and production, water treatment, cosmetics, pharmaceutics, food industry and chemical intermediates.

Abstract: Plastic beads, including polyamides and polystyrene beads crosslinked with divinylbenzene, having a curable resin coating are highly useful for sand control and/or hydraulic fracturing of subterranean. The curable resin coated plastic beads preferably have an apparent specific gravity less than about 1.5.

Abstract: In one aspect, this invention relates to the use of thermoset nanocomposite particles as components of drilling fluid, drill-in fluid, completion fluid, and workover fluid additive packages to reduce fluid losses to a formation and/or to enhance a wellbore strength. In another aspect, this invention relates to the use particles of specific gravity ranging from about 0.75 to about 1.75 as components of drilling fluid, drill-in fluid, completion fluid, and workover fluid additive packages to reduce fluid losses to a formation and/or to enhance a wellbore strength. Using embodiments of the invention, reduction of fluid loss and/or enhancement of wellbore strength may be achieved while working with water-based, oil-based, invert emulsion, or synthetic drilling muds. The currently most preferred embodiments of the invention use substantially spherical thermoset nanocomposite particles, possessing a specific gravity from approximately 1.02 to approximately 1.

Abstract: The present disclosure relates to drilling fluids for use in bitumen recovery from oil sands. In particular, the disclosure relates to a drilling fluid composition containing hydrophobically associating polymers which encapsulate the bitumen, and a method and use of the composition.

Abstract: The present application relates to granules of powdery mineral particles produced by spray granulation of a liquid slurry comprising powdery minerals particles having particle size below 10 m, at least one water-reducing agent and/or at least one binder agent and/or at least one dispersing agent. The application further relates to a method for producing such granules.

Abstract: A composition, apparatus and method for use in a wellbore is described. In one aspect, a composition may include a shape-conforming material and nanoparticles sufficient to absorb a selected form of energy to heat the shape-conforming material to near or above a glass transition temperature. A method of deploying an apparatus using such a composition may include placing the apparatus at a suitable location in a wellbore and exposing the composition to the selected energy to deploy the apparatus in the wellbore.

Abstract: A phenol-formaldehyde novolac resin having a low concentration of free phenol prepared by distilling residual phenol from a molten novolac resin and replacing at least a portion of the phenol with a solvent having a volatility equal to or less than phenol. Such modified novolac resins are suitable for the production of resin coated molding sands for shell molding and sand cores, as well as for the production of resin coated proppants for use in oil and gas recovery operations.

Abstract: A wellbore fluid having at least two phases, including a fluid phase and a solid phase. The solid phase is a powdered solid material coated with a polymer that is the reaction product of a polyether amine and a dialdehyde crosslinking agent. Preferably the polyether amine is a diamine and more preferably the compound acts as a shale hydration inhibitor. The dialdehyde crosslinking agent reacts with the polyether amine compound and forms the polymeric material coating the solid. The polymer is substantially solubilized when the pH of the fluid has a value of less than about 7.

Abstract: A method of delivering chemicals such as scale inhibitor into a wellbore producing fluids includes providing the chemicals, in a slow-release form, in a container located in the path of the production fluids so that the production fluids pass through the container. Preferably, the container is suspended in the production tubing and periodically retrieved from the well to be refilled.

Abstract: Use of polyaminomethylenephosphonates as dispersing and/or wetting and/or stabilizing agents in formulations for cements, detergents, ceramic materials, dyes, synthetic resins, and rubbers, drilling fluids, reverse osmosis, as a substitution of or in combination with commercial products suitable for the purpose, characterized in that said polyaminomethylenephosphonates have the formula. (I) wherein n is integer higher than 2, M is hydrogen or a cation selected from those of alkaline metals and the ammonium ion, and the residues R, the same or different, are independently selected from 1. —CH2PO3M2, 2. —CH2R1 with R1 selected from —CH2OH, —CHOHCH3, —CHOHCH2CL, —CHOHCH2OH, 3. —(CH2)Mso3M, m being equal to 3 or 4, 4. —CH2CH2R2 with R2 equal to —CONH2, CONH2, —CHO, —COOR3, —COOX, CN, R3 being either —CH3 or —C2H5 and X a cation selected from the meanings of M and from the fact that said polyaminomethylenephosphonates are present in the formulation of interest in a weight quantity of over 0.

Abstract: A fluid loss control pill or solution includes a polymer having a functional group that can be hydrolyzed by a base or a nucleophile. A method for fluid loss control in a subterranean formation includes placing a fluid loss control pill or solution in a wellbore penetrating the subterranean formation, wherein the fluid loss control pill or solution comprises a polymer having a functional group that can be hydrolyzed by a base or a nucleophile; and converting the polymer into a soluble form by hydrolyzing the functional group with a base or a nucleophile, when fluid loss control is no longer needed.

Abstract: Additive for a drilling fluid to block drilling-induced or pre-existing rock fractures comprising polymeric granules with a diameter distribution peak between 1000 and 200 microns and an average resiliency of at least 10% rebound after compression by a load of 200 N and uses thereof.

Abstract: Well bore servicing fluids are provided that include a thermally activated viscosification compound. Further, methods of servicing a well bore are provided that include displacing such a servicing fluid into the well bore, wherein a viscosity of the servicing fluid increases as it passes down the well bore due to its temperature increasing. Thus, the viscosity of the servicing fluid is effective to suspend solids therein when the servicing fluid is in the well bore. The servicing fluid may be, for example, a cement slurry, a drilling fluid, a gravel packing fluid, a fracturing fluid, a completion fluid, or a work-over fluid. In an embodiment, the thermally activated viscosification compound includes at least one water-soluble hydrophobically modified polymer comprising a hydrophobic substituent having from about 1 to about 22 carbon atoms.

Abstract: Of the many compositions provided herein, in one embodiment, the present invention provides a drill-in fluid comprising an aqueous base fluid, a viscosifier, a relative permeability modifier fluid loss control additive, and a degradable bridging agent comprising a degradable material capable of undergoing an irreversible degradation downhole.

Abstract: Of the many methods provided, in one embodiment, the present invention provides a method comprising: placing a drill-in fluid in a subterranean formation, the drill-in fluid comprising an aqueous base fluid, a viscosifier, a relative permeability modifier fluid loss control additive, and a degradable bridging agent comprising a degradable material capable of undergoing an irreversible degradation downhole; and forming a self-degrading filter cake comprising the bridging agent upon a surface within the formation whereby fluid loss through the self-degrading filter cake is reduced.

Abstract: It is proposed a new family of terpolymers based on repeating units of two different types of hydrophobic moieties modified with anionic charged groups. In a preferred embodiment, the first hydrophobic moiety is an aromatic compound such as styrene and the second hydrophobic moiety is a fatty acid. Depending on the modification rate, and on the neutralization degree, the aqueous solutions of the terpolymers have different rheological behavior, ranging from yield point fluid, shear-thickening and polysoaps.

Abstract: A wellbore fluid that includes an oleagninous continuous phase; a non-oleaginous phase; and a polymeric additive formed by reaction of at least one lipophilic epoxy modifier and at least one epoxide-reactive agent, wherein the at least one epoxide-reactive agent comprises at least one selected from lignins, tannins, biopolymers, starches, carboxy methyl cellulose, polyacrylates, polyacrylamides, and synthetic polymers is disclosed.