Abstract: Spacer fluids that are stable at temperatures up to at least 300° C. comprise water, polystyrene sulfonate and a mixture of particulate materials. The particulate materials may be chosen such that the mixture has at least a trimodal particle-size distribution. The fluids may further comprise inorganic clays, mutual solvents and surfactants.

Abstract: Propping compositions comprising: a hardenable, liquid external phase comprising an element selected from the group consisting of: a cement, a cement foam, a polymer, a resin, an aluminum, a flowable carrier fluid, and any combination thereof; and an internal phase that is either gas or liquid and that is immiscible with the external phase; wherein the internal phase exits the propping composition as the hardenable external phase hardens, leaving behind an hardened, interconnected porous network. Some propping compositions may require contact with a treatment for removal from the hardenable external phase and the treatment for removal may comprise at least one material selected from the group consisting of: an acid, a base, a chelant, an oxidizer, a solvent, and any combination thereof.

Abstract: Provided herein are, inter alia, compositions and methods for enhanced oil recovery in the presence of multivalent mineral cations. The aqueous and emulsion compositions provided herein include a boron oxygenate and may be useful for the recovery of unrefined petroleum materials from mineral-bearing reservoirs.

Abstract: A well treatment fluid comprising a Pickering particle emulsion comprising particles of a first liquid phase dispersed in a continuous second liquid phase, and comprising a plurality of colloidal particles adsorbed to a liquid-liquid interface between the first liquid phase and the second liquid phase. Methods, equipment and/or systems for treating a subterranean formation utilizing such treatment fluids are also disclosed.

Abstract: A wellbore treatment fluid is formed from an aqueous medium, a gas component, a viscosifying agent, and a surfactant. The surfactant is represented by the chemical formula: [R—(OCH2CH2)m—Oq—YOn]pX wherein R is a linear alkyl, branched alkyl, alkyl cycloaliphatic, or alkyl aryl group; O is an oxygen atom; Y is either a sulfur or phosphorus atom; m is 1 or more; n is a integer ranging from 1 to 3; p is a integer ranging from 1 to 4; q is a integer ranging from 0 to 1; and X is a cation. The fluid may be used in treating a subterranean formation penetrating by a wellbore by introducing the fluid into the wellbore. The fluid may be used in fracturing a subterranean formation penetrated by a wellbore by introducing the fluid into the formation at a pressure equal to or greater than the fracture initiation pressure.

Abstract: A well fracturing fluid is shown which includes an aqueous base fluid, a hydratable polymer, such as a guar gum, and a suitable crosslinking agent for crosslinking the hydratable polymer to form a polymer gel. The hydratable polymer has a higher molecular weight which is achieved by improvements in the processing of the guar split. The higher molecular weight polymer provides improved performance in well fracturing operations.

Abstract: A method for increasing the permeability of a geologic formation by fracturing includes the step of pumping a solution of a borohydride into a well bore. The solution may also include a basic material such as sodium hydroxide. This step may be followed by pumping a second acidic solution into the well bore.

Abstract: Breaking compositions are disclosed for controlled breaking of borate cross-linked fracturing fluids, and to method for making and using same, where the composition includes an oxidative component and an ester component.

Abstract: Composition comprising a plurality of particulates wherein at least some particulates are at least partially covered with a coating that impedes the intrusion of water into the particulates; and, a silica scale control additive, wherein the silica scale control additive is capable of suppressing silica scale build-up proximate the plurality of particulates. Some compositions further include a treatment fluid wherein and the silica scale control additive are present in the treatment fluid.

Abstract: Mineral particles may provide for wellbore fluids with tailorable properties and capabilities. In some instances, a dry wellbore additive may comprise a plurality of first mineral particles having a specific gravity of about 2.6 to about 20; a plurality of second mineral particles having a specific gravity of about 5.5 to about 20; a plurality of lubricant particles having a specific gravity of about 2.6 to about 20; wherein the first mineral particles, the second mineral particles, and the lubricant particles are different; and wherein the first mineral particles, the second mineral particles, and the lubricant particles have a multiparticle specific gravity of about 3 to about 20.

Abstract: A method of treating a subterranean formation. The method may include providing a fluid-loss control pill that comprises an aqueous base fluid, a gelling agent, and an internal breaker that is selected from the group consisting of inorganic delayed acids or inorganic salts. The method can include introducing the fluid-loss control pill into a subterranean formation, allowing the internal breaker to reduce the viscosity of the pill after a delay period, and allowing the fluid-loss control pill to break.

Abstract: Treatment of a subterranean formation can be conducted with viscosified treatment fluids that comprise a multifunctional boronic acid crosslinking agent. Methods for treating a subterranean formation can comprise providing a treatment fluid that comprises an aqueous base fluid, a gelling agent, and a multifunctional boronic acid crosslinking agent that comprises a copolymer comprising at least one boronic acid monomer unit and at least one water-soluble monomer unit; and introducing the treatment fluid into a subterranean formation.

Abstract: A method of increasing the fracture complexity in a treatment zone of a subterranean formation is provided. The subterranean formation is characterized by having a matrix permeability less than 1.0 microDarcy. The method includes the step of pumping one or more fracturing fluids into a far-field region of a treatment zone of the subterranean formation at a rate and pressure above the fracture pressure of the treatment zone. A first fracturing fluid of the one or more fracturing fluids includes a first solid particulate, wherein: (a) the first solid particulate includes a particle size distribution for bridging the pore throats of a proppant pack previously formed or to be formed in the treatment zone; and (b) the first solid particulate comprises a degradable material. In an embodiment, the first solid particulate is in an insufficient amount in the first fracturing fluid to increase the packed volume fraction of any region of the proppant pack to greater than 73%.

Abstract: Disclosed are compositions and methods for treating subterranean formations, in particular, oilfield stimulation compositions and methods using polymer viscosified fluid crosslinked with metal complexes with amino and/or phosphonic acids to provide an increased crosslinking temperature and a low pH sensitivity. The metal complexes can be used with borate crosslinkers to provide continuous viscosification as the temperature is increased.

Abstract: Fracturing fluid compositions and methods of fracturing subterranean formations using polyboronic compounds as crosslinking agents are provided. The compositions and methods of the present invention allow for lower polymer loadings because achieving higher fracturing fluid viscosities can be achieved using less polymer than in traditional crosslinked systems.

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

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

Abstract: The present invention is a cryogenic subterranean fracturing fluid, comprising a liquefied industrial gas and a first additive. The liquefied industrial gas may be liquefied carbon dioxide, liquefied nitrogen, or a blend of the two. The liquefied industrial gas mixture should be substantially free of water. In this context, substantially free of water means less than 10% water by volume, or preferably less than 5% water by volume. In addition to the first additive, a proppant may be added to the fracturing fluid. In addition to the biocide and/or proppant additional additives may be added to the liquefied industrial gas as required. Non-limiting examples of such additives include ozone, a friction reducer, an acid, a gelling agent, a breaker, a scale inhibitor, a clay stabilizer, a corrosion inhibitor, an iron controller, an oxygen scavenger, a surfactant, a cross-linker, a non-emulsifier, a Ph Adjusting agent, or any combination thereof.

Abstract: A treatment fluid made of mineral acid, viscoelastic surfactant, at least one of a fluoride source and a chelant, and optionally a corrosion inhibitor. A method of combining a mineral acid, viscoelastic surfactant, at least one of a fluoride source and a chelant, and optionally a corrosion inhibitor, in a fluid mixture. A method of contacting a low-temperature formation with a fluid mixture of mineral acid, viscoelastic surfactant, at least one of a fluoride source and a chelant, and optionally a corrosion inhibitor.

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: The present invention relates to compositions and methods for enhancing fracture conductivity. One embodiment of the present invention provides a method of providing a fracturing fluid and a flowable propping composition having a hardenable external phase and an internal phase where the internal phase is immiscible with the external phase; introducing the fracturing fluid into a subterranean formation; introducing the flowable propping composition into a fracture in the subterranean formation; allowing the hardenable external phase to form a hardened external phase in the fracture in the subterranean formation; and allowing the presence of the internal phase to be reduced from the hardened external phase thereby leaving a void volume in the hardened external phase.

Abstract: A method of treating a subterranean formation comprises providing a treatment fluid comprising: an aqueous fluid; a gelling agent, and a multifunctional boronic crosslinker comprising two or more boronic functional groups; and introducing the viscosified fluid into a subterranean formation.

Abstract: Polyboronic compounds and methods of making them are provided. The polyboronic compounds are useful as crosslinking agents. The polyboronic compounds are produced by contacting a polymeric amine with a trialkylborate in the presence of a solvent so that the resulting molecule has more than one B—N bond.

Abstract: A method comprises providing a treatment fluid comprising a gelling agent, an aqueous base fluid, a buffer composition comprising a plurality of salts, and a crosslinking agent; and contacting a subterranean formation with the treatment fluid. The aqueous base fluid is preferably seawater and the buffer composition includes one or more salts present in the treatment fluid from about 1 to about 1000 pounds per gallon of treatment fluid.

Abstract: Polyboronic compounds and methods of making them are provided. The polyboronic compounds are useful as crosslinking agents. The polyboronic compounds are produced by contacting a polymeric amine with a trialkylborate in the presence of a solvent so that the resulting molecule has more than one B—N bond.

Abstract: Incorporating water-based polymer breakers, such as oxidizers, enzymes and/or acids, into a mixture of an oil and oil-soluble surfactants creates an emulsion that can then perform as a dual-functional breaker for reducing the viscosity of hybrid fluids gelled with both a viscoelastic surfactant (VES) and a polymer. The outer phase of the dual-functional breaker emulsion is oil, e.g. a mineral oil, containing an oil-soluble surfactant that will, over time and with heat, break the VES portion of the gel. As it does so, the polymer breaker in the internal aqueous phase will be released to then break the polymer portion of the gel. The polymer breaker will not start to break the polymer gel before the oil-soluble surfactant starts to break the VES gel. The overall breaking using the emulsion is slower as compared to introducing the polymer breaker and the oil-soluble surfactant in a non-emulsified form.

Abstract: Methods that comprise selecting proppant for use in a fracturing fluid based on one or more factors, wherein the one or more factors comprise an interaction between the proppant and the fracturing fluid. Methods that comprise designing a treatment fluid that comprises a gelled base fluid and a particulate based on one or more factors, wherein the one or more factors comprise an interaction between the particulate and the gelled base fluid.

Abstract: A treatment fluid for treating a subterranean formation penetrated by a wellbore is formed from an aqueous medium, a diutan heteropolysaccharide having a tetrasaccharide repeating unit in the polymer backbone and a peroxide breaker. A method of treating a subterranean formation penetrated by a wellbore may be carried out by introducing the treatment fluid into the formation through the wellbore. Breaking aids or catalysts may also be used with the treatment fluid.

Abstract: Methods of treating a subterranean formation are disclosed, using a fluid including an essentially metal-free organic crosslinker selected from amines, diamines, poly amines, polyamino polymers, alcohols, polyols, polyhydroxy polymers, hydroxyl amines, peptides and proteins, combined with a polysaccharide or cellulosic material having oxidized functional groups. The fluid is then introduced into a wellbore penetrating the formation to contact the formation. The polysaccharide or cellulosic material may have aldehyde groups as one example of an oxidized group, or any other suitable oxidized functional group. The polysaccharide or the cellulosic material may be oxidized using at least one of an enzymes, oxidizers, photooxidation, bacteria, catalyst, or other suitable technique. The fluid may also further include an inorganic crosslinker.

Abstract: A proppant having low surface friction is described, which is useful in hydrocarbon recovery. Methods of making low surface friction proppants are further described, as well as uses thereof.

Abstract: Composition comprising a plurality of particulates wherein at least some particulates are at least partially covered with a coating that impedes the intrusion of water into the particulates; and, a silica scale control additive, wherein the silica scale control additive is capable of suppressing silica scale build-up proximate the plurality of particulates. Some compositions further include a treatment fluid wherein and the silica scale control additive are present in the treatment fluid.

Abstract: This invention relates to fluid compositions used in treating a subterranean formation. In particular, the invention is aqueous wellbore treatment compositions which are foams containing a viscosifying agent, a foam extender, a gas component, and a surfactant, as well as methods of forming such fluids, and uses thereof. The viscosifying agent may be a hydratable polymer, viscoelastic surfactant, or heteropolysaccharide. The foam extender may be a material such as a polyoxyalkyleneamines, ethylenepolyamines, tertiary polyamines, bicarbonate, carbonate, phosphate, or sesquicarbonate.

Abstract: Proppant used to keep open a fissure in a reservoir created by hydraulic or other action is disclosed. The proppant demonstrates a reduced specific gravity controlled by the geometry of the structure of the proppant. Proppant must be capable of withstanding the hydrostatic environment of the hydraulic pumping system, pass through a perforation in the casing of the well, travel into the fissure, and, upon reduction of hydrostatic pressure, withstand the closure pressure of the formation. A proppant having neutral buoyancy or substantial neutral buoyancy yet capable of withstanding the hydraulic and closure pressures is described that has a tubular structure hollow in the center with a wall of material sufficiently strong to withstand the majority of closure pressures.

Abstract: Proppant used to keep open a fissure in a reservoir created by hydraulic or other action is disclosed. The proppant demonstrates a reduced specific gravity controlled by the geometry of the structure of the proppant. Proppant must be capable of withstanding the hydrostatic environment of the hydraulic pumping system, pass through a perforation in the casing of the well, travel into the fissure, and, upon reduction of hydrostatic pressure, withstand the closure pressure of the formation. A proppant having neutral buoyancy or substantial neutral buoyancy yet capable of withstanding the hydraulic and closure pressures is described that has a tubular structure hollow in the center with a wall of material sufficiently strong to withstand the majority of closure pressures.

Abstract: The present invention relates to glass-ceramic proppants which can be used to prop open subterranean formation fractions, as well as other uses. Proppant formulations are further disclosed which use one or more proppants of the present invention. Methods to prop open subterranean formation fractions are further disclosed. In addition, other uses for the proppants of the present invention are further disclosed, as well as methods of making the glass-ceramic proppants.

Abstract: Proppants which can be used to prop open subterranean formation fractions are described. Proppant formulations which use one or more proppants of the present invention are described, as well as methods to prop open subterranean formation fractions, and other uses for the proppants and methods of making the proppants.

Abstract: Fracturing fluid compositions and methods of fracturing subterranean formations using polyboronic compounds as crosslinking agents are provided. The compositions and methods of the present invention allow for lower polymer loadings because achieving higher fracturing fluid viscosities can be achieved using less polymer than in traditional crosslinked systems.

Abstract: Emulsified acids have been used to increase production rates of oil and gas in carbonate reservoirs through acid fracturing and matrix acidizing operations. An emulsifier is used to emulsify the aqueous acid with an oil, usually diesel. Very small particles, such as colloidal clay particles and/or nanoparticles increase the stability of the emulsified acids over an elevated temperature range.

Abstract: The present invention relates to compositions useful for isolating a portion of a wellbore. In one embodiment, a composition includes a sealant composition containing a wellbore treatment fluid and a set modifier component. The sealant composition can be placed into the wellbore and subjected to ionizing radiation that alters the set modifier component, triggering the setting of the sealant composition.

Abstract: The present invention includes compositions relating to the setting of fluids or slurries in a wellbore. In one embodiment, a sealant composition having a fluid component and a polymeric additive component can be subjected to ionizing radiation. The ionizing radiation can cause bonding between polymeric additive components and create a polymer matrix within the sealant composition that increases the mechanical strength of the sealant composition.

Abstract: A method is described to predict the composition of favorable bridging agents for a particular situation in which the solution thermodynamics of the chemicals used in the composition of the bridging material is carefully evaluated. Wellbore service fluids are also described that contain materials such as sodium bicarbonate, a material such as a salt containing water in a crystal structure, a material containing at least one boron-oxygen bond, or a non-polymer material having low solubility at low temperatures and high solubility at temperatures close to an expected long-term static bottom hole temperature. The material is provided in aqueous medium in sufficient concentration in the aqueous medium so as to act as a diverting agent during a hydraulic fracturing procedure using the fluid. The wellbore service fluid is pumped through the wellbore and the flow of the fluid is diverted using a plug that subsequently substantially dissolves due to changes in temperature and/or pressure.

Abstract: Treatments and compounds useful in subterranean formations are discussed, with particular attention to those utilizing ceramic coated particulates. Certain embodiments pertain to particulates and particulate packs with ceramic coatings of subatomic thickness. Of these, certain methods may utilize ceramic coatings on particulates in a subterranean formation, certain methods may utilize ceramic coatings on particulate packs in a subatomic formation, and certain compounds may provide the features of both ceramic coatings and particulates.

Abstract: Treatment fluids comprising gelling agents that comprise crosslinkable polymers and certain biopolymers, and methods of use in subterranean operations, are provided. In one embodiment, the present invention provides a treatment fluid comprising: an aqueous base fluid; a crosslinking agent; and a gelling agent comprising a polymer that is a crosslinkable polymer, and a polymer that is a biopolymer wherein a molecule of the biopolymer (1) consists only of glucose, or (2) has a backbone comprising one or more units that comprise at least (a) one glucose unit and (b) one linear or cyclic pyranose-type monosaccharide unit, wherein (a) and (b) have different molecular structures.

Abstract: The invention provides a method made of steps of providing a composition comprising a first chemical component and a degradable protective layer, wherein the degradable protective layer is at least partially degradable when subject to temperature, pH or time; and introducing into a wellbore the composition and allowing the degradable protective layer to degrade and release the first chemical component.

Abstract: This invention relates to an aqueous-swellable and degradable diverting system and the use of the system in treating a subterranean formation penetrated by a wellbore. The diverting system comprises a carrier fluid and a partially dehydrated or anhydrous borate source material that does not swell or does not swell substantially when placed in contact with the carrier fluid. The carrier fluid is capable of carrying and placing the borate source material into a stimulation network substantially distanced from a wellbore. The carrier fluid may be a non-aqueous fluid, or when the average size of the borate source material is sufficient large, the carrier fluid may also be an aqueous fluid. Exposure of the diverting composition to sufficient amount of aqueous fluid swells the borate source material, bridges a desired portion of the stimulation network and then dissolves at least a portion of the diverting composition.

Abstract: A method comprises providing a treatment fluid comprising a gelling agent, an aqueous base fluid, a buffer composition comprising a plurality of salts, and a crosslinking agent; and contacting a subterranean formation with the treatment fluid. The method may be used in subterranean formation having a temperature greater than about 200° F., and the treatment fluid useful with the method may have a high shear recovery greater than 100%.

Abstract: A cross-linking system for hydratable polymers for using is formation fracturing applications is disclosed along with methods for using same, where the cross-linking system includes a reaction product of a transition metal alkoxide or alkanolate and a borate or borate generating reagent.

Abstract: A wellbore treatment fluid is formed from an aqueous medium, a gas component, a viscosifying agent, and a surfactant. The surfactant is represented by the chemical formula: [R—(OCH2CH2)m—Oq—YOn]pX wherein R is a linear alkyl, branched alkyl, alkyl cycloaliphatic, or alkyl aryl group; O is an oxygen atom; Y is either a sulfur or phosphorus atom; m is 1 or more; n is a integer ranging from 1 to 3; p is a integer ranging from 1 to 4; q is a integer ranging from 0 to 1; and X is a cation. The fluid may be used in treating a subterranean formation penetrating by a wellbore by introducing the fluid into the wellbore. The fluid may be used in fracturing a subterranean formation penetrated by a wellbore by introducing the fluid into the formation at a pressure equal to or greater than the fracture initiation pressure.

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 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).