Abstract: A method of altering the properties of a drilling fluid includes adding effective amounts of crushed or whole oilseeds or mixtures of crushed or whole oilseeds to a drilling fluid. The crushed or whole oilseeds or mixture of crushed or whole oilseeds are selected to impart any one of or a combination of effects including but not limited to: an increase in drilling fluid emulsion stability in oil-based or invert emulsion fluids, decreased specific gravity of the drilling fluid, seepage loss control, filtration control, oil wetting and deflocculation/dispersion, of entrained solids and/or reduced torque and drag of the drilling string.

Abstract: Methods and compositions that include a method of treating a subterranean formation comprising the steps of providing a carrier fluid comprising degradable balls that comprise a carboxylic acid, a fatty alcohol, a fatty acid salt, a fatty ester, a fatty acid salt, or a combination thereof, and introducing the carrier fluid to the subterranean formation during a treatment.

Abstract: Methods of improving shear recovery time of viscoelastic surfactant fluid systems are described, one method involving providing a viscoelastic surfactant fluid system comprising a major portion of a surfactant and a rheology enhancer in a concentration sufficient to shorten shear recovery time of the fluid system compared to shear recovery time of the fluid system absent the rheology enhancer, the rheology enhancer selected from aromatic sulfonates having a molecular weight of at least 500; and injecting the fluid system down a well. The rheology enhancer may be a lignosulfonate derived from wood pulping. Viscoelastic surfactant systems including the rheology enhancer are also described.

Abstract: Methods and compositions for forming a hydraulic fracture are disclosed herein. The methods and compositions make use of novel amphiphobic proppants. The amphiphobic properties of the disclosed proppant compositions provide several advantages over existing solutions. The hydrophobic nature of the proppant enhances recovery of fracture fluid from the fracture as well as prevents liquid build-up with the fracture. Additionally, the lipophobic nature of the proppant may enhance production of hydrocarbons from the fracture.

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: A method is provided for inhibiting scale in a liquid hydrocarbon system, including the steps of: providing a liquid hydrocarbon system; providing an aloe-derived scale inhibitor; and mixing the aloe-derived scale inhibitor with the liquid hydrocarbon system in amounts effective to inhibit formation of scale. The scale inhibitor is aloe gel 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: Emulsions, either water-in-oil or oil-in-water, may be formed by combining an aqueous component, a non-aqueous component and a surfactant in combination with fibers. The fibers decrease the time and energy required to form the emulsion and, in some cases, allow emulsion formation that would not be possible with the use of such fibers.

Abstract: A method is provided for inhibiting scale in a liquid hydrocarbon system, including the steps of: providing a liquid hydrocarbon system; providing an aloe-derived scale inhibitor; and mixing the aloe-derived scale inhibitor with the liquid hydrocarbon system in amounts effective to inhibit formation of scale. The scale inhibitor is aloe gel 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: The invention relates to a core which is formed from a raw material mixture comprising at least a solid powder resin and a further finely divided starting material, and which, in the thermally treated state, has a density of less than 2 g/cm3. The invention further relates to a process for producing cores, in which raw material components are mixed to give a raw material mixture and granulated to form cores, and the latter are subsequently subjected to a thermal treatment in the temperature range of 120° C. to 220° C.

Abstract: Among many things, in some embodiments, dual-function additives that enhance fluid loss control and the stability of viscoelastic surfactant fluids, and their associated methods of use in subterranean formations, are provided. In one embodiment, the methods comprise: providing a viscoelastic surfactant fluid that comprises an aqueous base fluid, a viscoelastic surfactant, and a dual-function additive that comprises a soap component; and introducing the viscoelastic surfactant fluid into at least a portion of a subterranean formation.

Abstract: A composition of matter and a method of sealing a permeable formation is provided incorporating the composition to reduce or eliminate lost circulation in permeable formations. The composition comprises one or more sealing components, ranging in size from approximately 10 to approximately 750 microns, a wetting component, a viscosifier component and an activator or flocculant. A dry mixture of the components may be added directly from the bag to the drilling mud to the permeable formation and will not set up inside the drill string. The mixture will seal the formation in an aqueous or organic environment, thus removing the need to form a pill in a slugging pit prior to introduction. The mixture dewaters at a rapid rate without regard to the time and temperature required for curing agents or other additives. The mixture does not require additional agents such as defoamers, accelerators, retarders or spacers to dewater and set as a solid plug.

Abstract: The present invention provides methods to maintain fracture conductivity in subterranean formations. In one embodiment, the methods comprise: providing a first treatment fluid, a second treatment fluid, and a consolidating agent; injecting the first treatment fluid into the subterranean formation at a pressure sufficient to create one or more fractures in the subterranean formation; injecting the second treatment fluid into the subterranean formation to increase the permeability of at least a portion of the subterranean formation comprising at least a portion of the one or more fractures; and injecting the consolidating agent into a portion of the subterranean formation in an amount sufficient to at least partially stabilize at least a portion of the subterranean formation.

Abstract: A completion and workover fluid composition comprising, water and at least one rheology modifier and/or fluid loss control agent, and at least one other ingredient selected from the group consisting of inorganic salts, shale inhibitors, corrosion inhibitor, biocide, defoamers and finely divided solids particles (e.g., bentonite, attapulgite, sepiolite, calcium carbonate, etc.), depending upon the desired attributes, wherein the rheology modifier and/or the fluid loss control agent is an ethoxylated raw cotton linters or a modified ethoxylated raw cotton linters. The ethoxylated raw cotton linters provides comparable or better rheology and viscosity properties compared to high molecular weight commercial HECs made from purified cotton linters. These ethoxylated raw cotton linters derivatives are suitable for applications in oil-well servicing fluids, particularly to enhance functional properties of completion and workover fluids used during oil-well drilling operations.

Abstract: A method of heterogeneous proppant placement in a subterranean fracture is disclosed. The method comprises injecting well treatment fluid including proppant (16) and proppant-spacing filler material called a channelant (18) through a wellbore (10) into the fracture (20), heterogeneously placing the proppant in the fracture in a plurality of proppant clusters or islands (22) spaced apart by the channelant (24), and removing the channelant filler material (24) to form open channels (26) around the pillars (28) for fluid flow from the formation (14) through the fracture (20) toward the wellbore (10). The proppant and channelant can be segregated within the well treatment fluid, or segregated during placement in the fracture. The channelant can be dissolvable particles, initially acting as a filler material during placement of the proppant in the fracture, and later dissolving to leave the flow channels between the proppant pillars.

Abstract: Methods are disclosed for improved sand control, fines control, load recovery and well productivity, where the compositions comprise reaction products of an amine and a phosphate-containing compound.

Abstract: Disclosed embodiments relate to compositions and methods for using a composite particulate comprising a cellulosic fiber and a filler as a lost-circulation material. An example of a method of controlling lost circulation in a subterranean method, comprises contacting a subterranean formation with a fluid comprising a base fluid and a lost circulation material, wherein the lost circulation material comprises a composite particulate, and wherein the composite particulate comprises a cellulosic fiber and a filler. An example method of cementing comprises introducing a cement composition into a well bore penetrating a subterranean formation, wherein the cement compositions comprises a cement, water, and a lost-circulation material, and wherein the lost-circulation material comprises a lost-circulation material, and wherein the lost-circulation material comprises a cellulosic fiber and a filler. Example compositions include lost-circulation materials, treatment fluids and cement compositions.

Abstract: Provided are methods of modifying the surface stress-activated reactivity of proppant particulates used in subterranean operations. In one embodiment, the methods comprise: providing a plurality of particulates, at least one of which comprises a mineral surface; providing a surface-treating reagent capable of modifying the stress-activated reactivity of a mineral surface of a particulate; and allowing the surface-treating reagent modify the stress-activated reactivity of at least a portion of the mineral surface of at least one particulate. In other embodiments, the methods comprise the use of particulates comprising a modified mineral surface in fluids introduced into subterranean formations.

Abstract: A material and method for treating a fractured formation penetrated by a wellbore includes providing a quantity of resin coated particles having a particle size of from about 0.2 mm to about 2.35 mm. A quantity of smaller deformable or non-deformable particles is combined with the resin coated particles to form a generally uniform consolidated particle pack when mixed together and subjected to at least one of heat and pressure. A slurry of the particles is formed with a carrier fluid capable of suspending the particles. The slurry of particles is introduced into the wellbore of the formation. The resin coated particles and smaller deformable particles thus may form a consolidated particle pack in at least a portion of the fractures of the formation.

Abstract: The present invention provides a method for recovering oil from a subterranean reservoir using waterflooding, wherein the flooding fluid used in the waterflooding process comprises water and one or more of 1,3-propanediol, oligomers of 1,3-propanediol and polymers of 1,3-propanediol. The use of 1,3-propanediol, oligomers and/or polymers thereof is expected to increase the recovery of oil by improving both the oil/water mobility ratio and the sweep efficiency in reservoirs with a high degree of heterogeneity.

Abstract: Compositions and methods pertaining to the ultrafine grinding of soft materials are disclosed. In one embodiment, a method comprises the step of mixing a soft material with an additive to form a mixture. The method further comprises raising the temperature of the mixture to at least the glass transition temperature of the soft material. The method further comprises cooling the temperature of the mixture. The method further comprises grinding the mixture to form ultrafine particles that comprise at least a portion of the soft material.

Abstract: Methods are provided that include a method comprising providing a treatment fluid comprising at least a plurality of expandable particulates comprising a swellable elastomer composition. In some embodiments the expandable particulates may comprise a swellable elastomer and a filler material. In some embodiments the expandable particulates may comprise a solid particulate that has been at least partially coated with a swellable elastomer composition. In some embodiments, the treatment fluid may be placed into at least a portion of a subterranean formation at a pressure sufficient to create or enhance at least one fracture in the subterranean formation. Additional methods are also provided.

Abstract: The invention provides a method of altering the properties of a drilling fluid by adding effective amounts of crushed or whole oilseeds or mixtures of crushed whole oilseeds to a drilling fluid. The crushed or whole oilseeds or mixture of crushed or whole oilseeds are selected to impart any one of or a combination of effects including but not limited to: an increase in drilling fluid emulsion stability in oil-based or invert emulsion fluids, decreased specific gravity of the drilling fluid, seepage loss control, filtration control, oil wetting and deflocculation/dispersion, of entrained solids and/or reduced torque and drag of the drilling string.

Abstract: A fracturing fluid or crosslinking composition suitable for use at high temperature (275-340° F., 135-171° C.) comprising (a) an aqueous liquid, (b) brine, (c) a thermal stabilizer, (d) a non-delaying alkaline buffer sufficient to provide a pH less than 9, (e) an organic acid, (f) hydroxypropyl guar and (g) a zirconium crosslinking agent. The composition is useful as a fracturing fluid in oil field applications, for example, for hydraulically fracturing a subterranean formation or selectively plugging a permeable zone or leak in a subterranean formation.

Abstract: Methods of improving shear recovery time of viscoelastic surfactant fluid systems are described, one method involving providing a viscoelastic surfactant fluid system comprising a major portion of a surfactant and a rheology enhancer in a concentration sufficient to shorten shear recovery time of the fluid system compared to shear recovery time of the fluid system absent the rheology enhancer, the rheology enhancer selected from aromatic sulfonates having a molecular weight of at least 500; and injecting the fluid system down a well. The rheology enhancer may be a lignosulfonate derived from wood pulping. Viscoelastic surfactant systems including the rheology enhancer are also described.

Abstract: The present invention provides a method for enhancing the recovery of oil from a subterranean reservoir using waterflooding, wherein the flooding fluid used in the waterflooding process comprises water and comminuted feathers. The use of comminuted feathers is expected to increase the recovery of oil by improving sweep efficiency.

Abstract: A composite of a well treatment agent adsorbed onto a water-insoluble adsorbent is useful in the treatment of oil and gas wells and may be introduced, as a well treatment fluid, with a carrier fluid. The water-insoluble adsorbent may be activated carbon, silica particulate, precipitated silica, zeolite, diatomaceous earth, ground walnut shells, fuller's earth and organic synthetic high molecular weight water-insoluble adsorbents. Suitable as the well treatment agent are scale inhibitors, corrosion inhibitors, paraffin inhibitors, salt inhibitors, gas hydrate inhibitors, asphaltene inhibitors, oxygen scavengers, biocides, foaming agent, emulsion breakers and surfactants.

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 cleaning a work string which may have been used to inject drilling muds, cement slurries, cement displacement materials and the like into a well where the work strong may contain drilling mud residues, cement slurry residues, cement slurry displacement materials, pipe thread lubricants, pipe dope and the like, as well as corrosion on the inside of the work string by injecting a dispersion slug into and recovering the dispersion slug from the work string.

Abstract: The present invention provides thermoplastic coated proppants and methods for preparing the thermoplastic coated proppants. Methods for using these proppants in subterranean well formations and hydraulic fracturing operations, for example, are also disclosed.

Abstract: Hollow non-porous metallic spheres may be used in treatment of subterranean formations, including hydraulic fracturing and sand control methods, such as gravel packing. The spheres typically having a diameter ranging from about 4 mesh to about 100 mesh. When employed in deep water environments having high closure stresses, the spheres have a thicker wall and are characterized by the higher ASG, typically between 2.5 to about 4.0. The ASG of the spheres, when less harsh environments are encountered, is generally ultra lightweight (ULW) with an ASG less than or equal to 2.0. Fracture conductivity may be increased by the placement of the hollow non-porous metallic spheres as a partial monolayer.

Abstract: A method is provided for reducing lost circulation when aqueous, oil, or synthetic based drilling fluid is used. The method includes injecting two fluids into the well bore and lost circulation zone. The first fluid is an aqueous liquid containing at least one polymer capable of absorbing water in an alkaline environment. The aqueous liquid has a pH that inhibits at least one polymer from absorbing water. The second fluid contains a hardening composition in a base fluid having a pH sufficient to increase the pH in situ to allow at least one polymer to absorb water and expand with the absorbed water and substantially increase in size to close off the lost circulation zone and allow the hardening composition to create a plug in the well bore and set up.

Abstract: Methods of improving shear recovery time of viscoelastic surfactant fluid systems are described, one method involving providing a viscoelastic surfactant fluid system comprising a major portion of a surfactant and a rheology enhancer in a concentration sufficient to shorten shear recovery time of the fluid system compared to shear recovery time of the fluid system absent the rheology enhancer, the rheology enhancer selected from aromatic sulfonates having a molecular weight of at least 500; and injecting the fluid system down a well. The rheology enhancer may be a lignosulfonate derived from wood pulping. Viscoelastic surfactant systems including the rheology enhancer are also described.

Abstract: A method for minimizing the amount of metal crosslinked viscosifier necessary for treating a wellbore with proppant or gravel is given. The method includes using fibers to aid in transporting, suspending and placing proppant or gravel in viscous carrier fluids otherwise having insufficient viscosity to prevent particulate settling. Fibers are given that have properties optimized for proppant transport but degrade after the treatment into degradation products that do not precipitate in the presence of ions in the water such as calcium and magnesium. Crosslinked polymer carrier fluids are identified that are not damaged by contaminants present in the fibers or by degradation products released by premature degradation of the fibers.

Abstract: A composition comprising a fatty acid alkyl ester; at least one of a surfactant and a colloid; and an acid.

Abstract: A material and method for treating a fractured formation penetrated by a wellbore includes providing a quantity of resin coated particles having a particle size of from about 0.2 mm to about 2.35 mm. A quantity of smaller deformable or non-deformable particles is combined with the resin coated particles to form a generally uniform consolidated particle pack when mixed together and subjected to at least one of heat and pressure. A slurry of the particles is formed with a carrier fluid capable of suspending the particles. The slurry of particles is introduced into the wellbore of the formation. The resin coated particles and smaller deformable particles thus may form a consolidated particle pack in at least a portion of the fractures of the formation.

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: A method is provided for inhibiting scale in a liquid hydrocarbon system, including the steps of: providing a liquid hydrocarbon system; providing an aloe-derived scale inhibitor; and mixing the aloe-derived scale inhibitor with the liquid hydrocarbon system in amounts effective to inhibit formation of scale. The scale inhibitor is aloe gel 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: The invention discloses an additive for weighted aqueous slurries to reduce lost circulation during well drilling operations, a method of preparing the additive, and a method of reducing lost circulation utilizing the additive. The additive comprises a hardenable alkaline composition comprising mixtures of diatomaceous earth, finely ground paper, a hydrophobic liquid, micronized cellulose and lime. The hydrophobic liquid decreases the time required to prepare the weighted aqueous slurries, i.e., pills, containing the additive.

Abstract: A method for minimizing the amount of metal crosslinked viscosifier necessary for treating a wellbore with proppant or gravel is given. The method includes using fibers to aid in transporting, suspending and placing proppant or gravel in viscous carrier fluids otherwise having insufficient viscosity to prevent particulate settling. Fibers are given that have properties optimized for proppant transport but degrade after the treatment into degradation products that do not precipitate in the presence of ions in the water such as calcium and magnesium. Crosslinked polymer carrier fluids are identified that are not damaged by contaminants present in the fibers or by degradation products released by premature degradation of the fibers.

Abstract: A circulation loss combination for water-based drilling fluid system(s) comprising: a first amount of alkali metal silicate; a second amount of water insoluble particulate; and, a quantity of water soluble activating agent effective to reduce the pH of the water-based drilling fluid system to a value sufficiently low to form an effective circulation loss structure at a desired period of time after addition to the water-based drilling fluid system.

Abstract: An additive for controlling filtration loss from a well working fluid in contact with a permeable formation, which comprises sugar cane ash, or sugar cane ash and a cellulose-like material, or sugar cane ash, a cellulose-like material and an oleaginous liquid, wherein the sugar cane ash and cellulose-like material have a particle size no more than 300 microns.

Abstract: A method is provided for reducing lost circulation when aqueous, oil, or synthetic based drilling fluid is used. The method includes injecting two fluids into the well bore and lost circulation zone. The first fluid is an aqueous liquid containing at least one polymer capable of absorbing water in an alkaline environment. The aqueous liquid has a pH that inhibits at least one polymer from absorbing water. The second fluid contains a hardening composition in a base fluid having a pH sufficient to increase the pH in situ to allow at least one polymer to absorb water and expand with the absorbed water and substantially increase in size to close off the lost circulation zone and allow the hardening composition to create a plug in the well bore and set up.

Abstract: Methods and compositions for placing particulate materials in subterranean zones penetrated by well bores. In one embodiment, the methods comprise: providing a compacted particulate material fluid that comprises a compacted particulate material, and a foam within the pore spaces of the compacted particulate material, the foam comprising a pressurized gas and a liquid solution of a foam forming surfactant; and pumping the compacted particulate material fluid into the subterranean zone.

Abstract: For tubing/casing annulus plug treatment to plug a well, a tubing/casing annulus plug additive including a dry mixture of water soluble crosslinkable polymer, a crosslinking agent, a filter aid, and an optional reinforcing material, preferably of fibers and/or comminuted plant materials. The method of forming a tubing/casing annulus plug fluid includes contacting the additive with water or an aqueous solution, with a method of plugging the tubing/casing annulus of a well further including the step of injecting the fluid into the annulus.

Abstract: For well plug treatment to plug an abandoned well, a well plug additive including a dry mixture of water soluble crosslinkable polymer, a crosslinking agent, and filter aid, and optionally, a reinforcing material preferably of fibers and/or comminuted plant materials. The method of forming a well plug fluid includes contacting the additive with water or an aqueous solution, with a method of plugging the well further including the step of injecting the fluid into the wellbore.

Abstract: For well kill treatment to prevent the intrusion of formation fluids into the wellbore while the well is open, a well kill additive including a dry mixture of water soluble crosslinkable polymer, a crosslinking agent, filter aid, and optionally, a reinforcing material of fibers and/or comminuted plant materials. The method of forming a well kill fluid includes contacting the additive with water or an aqueous solution, with a method of conforming the formation further including the step of injecting the fluid into the wellbore.

Abstract: For tubing/casing annulus plug treatment to plug a well, a tubing/casing annulus plug additive including a dry mixture of water soluble crosslinkable polymer, a crosslinking agent, and a reinforcing material of fibers and/or comminuted plant materials. The method of forming a tubing/casing annulus plug fluid includes contacting the additive with water or an aqueous solution, with a method of plugging the tubing/casing annulus of a well further including the step of injecting the fluid into the annulus.

Abstract: A method and composition is provided for sealing a subterranean zone penetrated by a well bore to restore lost circulation. In one embodiment, the composition comprises a pellet comprising a mixture of lost circulation materials (LCMs).

Abstract: A composition for sealing porous subterranean formations comprises a mixture of a water-swellable clay and a water insoluble, water absorbent, water-swellable polymer, wherein the mixture is coated with a material that is resistant to penetration by water. The water penetration resistant material helps the delay the onset of swelling of the clay and polymer until it reaches the formations intended for sealing. Mixing the clay with the water-swellable polymer prior to coating assists in coating of the water-swellable polymer with the water penetration resistant material. The coated mixture can be suspended in an aqueous liquid, and then pumped into a subterranean cavity to seal porous formations therein.

Abstract: The invention provides a method and fluid for drilling or servicing a well in a subterranean formation containing lost circulation zones or depleted, low pressure reservoirs. The fluid comprises an aqueous liquid having dispersed therein a viscosifier which increases the low shear rate viscosity of the fluid to at least 10,000 centipoise, an aphron-generating surfactant, and aphrons, wherein the fluid contains less than about 20% by volume of aphrons preferably generated by the turbulence and pressure drop as the fluid exits the drill bit in the vicinity of the formation. The method of drilling a wellbore in a subterranean formation comprises continuously re-circulating, while drilling, such a drilling fluid.