Abstract: A method of servicing a wellbore comprising placing a wellbore servicing fluid comprising a modified friction reducer into the wellbore. A modified friction reducer comprising a degradable polymer having functional degradable moieties, a polymer having a molecular weight of from about 5M to about 30M, a polymer having a PDI of from about 1.0 to about 2.5, a weakly crosslinked polymer, or combinations thereof.

Abstract: Disclosed and claimed is a composition and method of inhibiting the formation of hydrate agglomerates in a fluid comprising water, gas, and optionally liquid hydrocarbon comprising adding to the fluid an effective anti-agglomerant amount of the following formula and optionally salts thereof: wherein each R1 is independently absent, C1-C10 alkyl, benzyl, or H; wherein R2 is C1-C10 alkyl; wherein R3 C1-C10 alkyl; and wherein R4 is C4-C22 alkyl or alkenyl.

Abstract: A method of treating a medium for water fracturing is disclosed, the method comprises: introducing at least one biocide and at least one metabolic inhibitor in the medium, using the medium for water fracturing. In another aspect a method of controlling the post-fracture reservoir souring by the metabolic activities of sulfate reducing bacteria of a well is described: at least one biocide and at least one metabolic inhibitor are introduced in a medium made of water, the medium is used for fracturing the well, and the medium remains in the reservoir to kill and/or inhibit growth of sulfate reducing bacteria.

Abstract: According to one aspect of the invention, a method of converting an oxy halide salt into a halide dioxide in a reaction zone under certain conditions is provided. More specifically, the method includes generating chlorine dioxide from a stable composition comprising an oxy halide salt by introducing said composition to a reducing agent and minimum temperature within the reaction zone. According to another aspect of the invention, a composition for a stable chlorine dioxide precursor comprising an oxy halide salt is provided.

Abstract: A method of cleaning a wellbore prior to the production of oil or gas, wherein the wellbore has been drilled with an invert emulsion drilling mud that forms an invert emulsion filter cake is disclosed. The method may include circulating a breaker fluid into the wellbore, where the breaker fluid includes a non-oleaginous internal phase and an oleaginous external phase, where the non-oleaginous phase includes a water soluble polar organic solvent, a hydrolysable ester of a carboxylic acid, and a weighting agent, and the oleaginous external phase includes an oleaginous fluid and an emulsifier, and where the hydrolysable ester is selected so that upon hydrolysis an organic acid is released and the invert emulsion of the filter cake breaks.

Abstract: A method of cleaning a wellbore prior to the production of oil or gas is disclosed, wherein the wellbore has been drilled with an invert emulsion drilling mud that forms an invert emulsion filter cake. The method may include the steps of circulating a breaker fluid into the wellbore, where the breaker fluid includes an aqueous fluid, a water soluble polar organic solvent, a hydrolysable ester of a carboxylic acid, and a weighting age, and where the hydrolysable ester is selected so that upon hydrolysis an organic acid is released and the invert emulsion of the filter cake breaks.

Abstract: An aqueous composition for removing scale deposits, especially on subsea equipment and a method of using the same is described. The aqueous composition comprises (a) a potassium phosphate compound; and (b) acetic acid. The composition is capable of dissolving away into seawater and poses little or no risk to the environment.

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: Aqueous well treatment fluid compositions are disclosed comprising an aqueous fluid containing polymer or copolymer for modifying fluid viscosity of the aqueous fluid and, in addition, an agent for effecting a controlled reduction in the aqueous fluid viscosity in a subterranean environment. The viscosity-reducing agent comprises a dilute concentration of peracetic acid. A method of using such compositions in oil- and gas-field treatment operations is also disclosed.

Abstract: A non-aqueous wellbore servicing fluid comprising a fluid loss additive wherein the fluid loss additive comprises the reaction product of (i) a functional polymer and (ii) an oligomerized fatty acid. A method of conducting an oil-field operation comprising placing a non-aqueous wellbore servicing fluid downhole wherein the non-aqueous wellbore servicing fluid comprises a fluid loss additive comprising the reaction product of (i) a functional polymer and (ii) an oligomerized fatty acid.

Abstract: The present invention relates to bridging agents for use in subterranean formations, to well drill-in and servicing fluids comprising such bridging agents, and to methods of using such bridging agents and well drill-in and servicing fluids in subterranean drilling operations. An example of a well drill-in and servicing fluid of the present invention comprises a viscosified fluid, a fluid loss control additive, and a bridging agent comprising a degradable material.

Abstract: Processes for producing alkyl esters useful as base fluids in oil-based mud compositions. The alkyl esters are produced from raw material waste oil that include vegetable oil. The raw material waste oil can be obtained from the food industry, such as from food chains. The raw material waste oil is purified by removing impurities from it. The raw material waste oil is then esterified with an alcohol in the presence of a catalyst. The resulting alkyl ester products are then separated from triglycerides. The alkyl ester products are then washed and dried.

Abstract: A method of fracturing a subterranean formation comprising at least in part shale formation, comprises providing a carrier fluid; providing a particulate blend including a first amount of particulates having a first average particle size between about 100 and 2000 microns and a second amount of particulates having a second average particle size between about three and twenty times smaller than the first average particle size, such that a packed volume fraction of the particulate blend exceeds 0.75; combining the carrier fluid and the particulate blend into a fracturing slurry; fracturing the formation with the fracturing slurry to create at least a fracture; and removing the second amount of particulates from the fracture.

Abstract: Consolidation fluids comprising: an aqueous base fluid comprising a hardening agent; an emulsified resin having an aqueous external phase and an organic internal phase; a silane coupling agent; and a surfactant. The consolidation fluid itself may be emulsified and further comprise an emulsifying agent. The consolidation fluid may also be foamed in some cases.

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: A fluid may contain nanoparticles and a base fluid where the base fluid may be a non-aqueous fluid. The base fluid may be, but is not limited to a drilling fluid, a completion fluid, a production fluid, and/or a stimulation fluid. The fluid may have at least one property, such as but not limited to a dielectric constant ranging from about 5 to about 10,000, an electrical conductivity ranging from about 1×10?6 S/m to about 1 S/m, and combinations thereof. The non-aqueous fluid may be a brine-in-oil emulsion, or a water-in-oil emulsion, and combinations thereof. The addition of nanoparticles to the base fluid may modify the electrical properties of the fluid.

Abstract: Of the many compositions and methods provided herein, an example method includes a method of treating a subterranean formation that comprises combining components comprising water and a density-matched suspension to prepare a treatment fluid, wherein the density-matched suspension comprises a suspending liquid and a solid particle suspended in the suspending liquid, and introducing the treatment fluid into a well bore. An example composition includes a suspension that comprises a suspending liquid comprising a hydrophobic liquid, wherein the hydrophobic liquid hydrolyzes when placed in contact with an aqueous fluid to form hydrophilic products, and a solid particle suspended in the suspending liquid, wherein the suspension is a density-matched suspension.

Abstract: Aqueous compositions including a mild alkaline agent (i.e. compound of formula (I) or (V)) and a surfactant are provided. The compositions and methods of using the same are particularly useful in the field of enhanced oil recovery.

Abstract: Emulsions for use in a well including: (a) a water-insoluble resinous material; (b) water; and (c) an emulsifier, wherein the emulsifier comprises a non-ionic, a cationic, or a zwitterionic emulsifier; wherein the continuous phase of the emulsion comprises the water; wherein a dispersed phase of the emulsion comprises the resinous material; wherein the dispersed phase is in the form of droplets having a size distribution range such that at least 50% of the droplets have a size of 0.5 micrometers-500 micrometers; wherein the resinous material of the droplets is in a concentration of at least 5% by weight of the water; and wherein the composition of the droplets has a viscosity of less than 2,000 Poise measured at 20° F. Methods include the steps of: (a) forming an emulsion described above; and (b) introducing the emulsion into a portion of a subterranean formation.

Abstract: A treatment fluid for a well includes: (a) a water-soluble polymer, wherein the water-soluble polymer comprises a polymer of at least one non-acidic ethylenically unsaturated polar monomer; (b) an organic crosslinker comprising amine groups, wherein the organic crosslinker is capable of crosslinking the water-soluble polymer; (c) a weak organic acid; and (d) water; wherein the treatment fluid is a crosslinkable polymer composition.

Abstract: Methods and systems relating to in situ decomposition of carbonyls at high temperature for fixing incomplete and failed well seals, are described. According to one embodiment, a method, comprises injecting a sealing agent into a subterranean well having sealing channels or voids in well casings. An alkaline-earth carbonate precipitate is formed from the decomposition of a carbonyl compound. The sealing agent includes the carbonyl compound and an alkaline-earth halide salt.

Abstract: This invention refers to the manufacture and use of a petroleum asphaltene handler additive compound, which when applied in heavy oil, it makes asphaltenes to remain in suspension or dissolve, producing a viscosity reduction effect, this way avoiding formation of asphaltenic conglomerates precipitation in oil wells, storage tanks, as well as keeping pipelines from being obstructed. The components of this new additive compound achieve such a molecular coupling that the final liquid may be miscible in all types of oil. There are currently solubility models with the use of different methods for handling asphaltenes; some of them use solvents which generate other problems to the oil's physical and chemical stability, and in other cases, for example, the use of steam or heat, it becomes a temporary solution because the oil returns to the initial conditions at the end because reversible processes are utilized.

Abstract: A breaker fluid for breaking a filtercake in a wellbore. The fluid including a hydrolysable ester of carboxylic acid, and a chelant, an alkyl glycoside, or a combination thereof. The breaker fluid may be pre-mixed and include an amount of water less than required to completely hydrolyze the ester.

Abstract: Adding a lubricant having a metal stearate and polytetrafluoroethylene (PTFE) to a downhole fluid may lubricate a first surface once the downhole fluid has been circulated within a subterranean reservoir wellbore. Friction, torque, and/or drag may be reduced when the lubricated first surface contacts a second surface. The first surface may be or include, but is not limited to a wellbore casing, a drill string, a pipe, a formation, a drill bit, a metal surface within a mud motor, formation evaluation tool, at least one drilling tool, and combinations thereof. One or both of the first and second surfaces may be metal. The downhole fluid may be or include, but is not limited to, a drilling fluid, a completion fluid, a fracturing fluid, a drill-in fluid, a workover fluid, and combinations thereof.

Abstract: A method of treating a hydrocarbon containing formation is described. The method includes (a) providing a hydrocarbon recovery composition to at least a portion of the hydrocarbon containing formation, wherein (i) when the salinity of the brine is from about 2 wt % to about 4 wt %, the composition comprises a blend of a C20-24 internal olefin sulfonate and a C24-28 internal olefin sulfonate wherein the weight ratio of the C20-24 internal olefin sulfonate to the C24-28 internal olefin sulfonate is from about 90:10 to about 70:30 and (ii) when the salinity of the brine is greater than about 4 wt % up to about 13 wt % the composition comprises a blend of a C20-24 internal olefin sulfonate and a C15-18 internal olefin sulfonate wherein the weight ratio of the C20-24 internal olefin sulfonate to the C15-18 internal olefin sulfonate is from about 90:10 to about 70:30; and (b) allowing the composition to interact with hydrocarbons in the hydrocarbon containing formation.

Abstract: A treatment fluid comprises: water; a formate; and a corrosion inhibitor, wherein the corrosion inhibitor is capable of providing: (A) a pH of at least 10; and (B) a corrosion rate equal to or less than 4 mils per year wherein carbon dioxide accounts for at least 100 psi (0.7 MPa) of the total pressure, for a test fluid consisting essentially of: the water; the formate; and the corrosion inhibitor, and in the same proportions as in the treatment fluid, whereas a substantially identical test fluid without the corrosion inhibitor has a pH of less than 10 and a corrosion rate of greater than 4 mils per year under the testing conditions. The treatment fluid further comprises a scale inhibitor. A method of treating a portion of a well comprises: forming the treatment fluid; and introducing the treatment fluid into the well.

Abstract: Clay is stabilized in methods for drilling of wells and other formation treatment for hydrocarbon production by the addition to the drilling or other fluid including a choline compound together with an formation control additive.

Abstract: Disclosed herein are an acid emulsion fluid for use in sealing target portions of a hydrocarbon producing formation penetrated by a wellbore and the method of use thereof for fluid loss control.

Abstract: Breaker nanoparticles may be added to gelled aqueous fluids where the gelled aqueous fluid may include an aqueous base fluid, e.g. a drilling fluid, gelled with at least one viscoelastic surfactant (VES) in an amount to increase the viscosity of the aqueous base fluid. The addition of the breaker nanoparticles may reduce the viscosity, or break the gel, of the gelled aqueous fluid by the direct or indirect action of the breaker nanoparticles. The breaker nanoparticles may be or include, but are not limited to inorganic semiconductor particles, organic semiconductor particles, and combinations thereof.

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: A grouting composition for use in insulating a portion of a tubular located inside an enclosed conduit comprises: (A) an oil-swellable binding material comprising a organophilic clay; and (B) a hydrocarbon liquid, wherein the hydrocarbon liquid is the continuous phase of the grouting composition; and (C) an insulating material comprising a hollow microsphere, wherein after the grouting composition has set, the grouting composition has a thermal conductivity of less than 0.3 BTU/hr·ft·° F.

Abstract: Methods of reducing the viscosity of a viscosified treatment fluid; providing a clean-up composition comprising a carboxylic acid; a chlorite-based breaker system comprising an alkali metal compound and an activator wherein the activator comprises a metal and an amine. Placing a viscosified treatment fluid in a subterranean formation via a well bore penetrating the subterranean formation; first contacting the viscosified treatment fluid with the chlorite-based breaker; and then contacting the viscosified treatment fluid with the clean-up composition; and, allowing the viscosity of the viscosified treatment fluid to reduce.

Abstract: Of the many methods provided herein, one method of reducing the viscosity of a viscosified treatment fluid includes: providing a clean-up composition comprising a carboxylic acid; providing a chlorite-based breaker system; providing a viscosified treatment fluid; placing the viscosified treatment fluid in a subterranean formation via a well bore penetrating the subterranean formation; contacting the viscosified treatment fluid with the clean-up composition; contacting the viscosified treatment fluid with the chlorite-based breaker; and allowing the viscosity of the viscosified treatment fluid to reduce. Also provided herein are methods that include a method of reducing polymeric residue from a subterranean formation that includes: placing a clean-up composition and a chlorite-based breaker system in a subterranean formation in contact with an amount of polymeric residue; and allowing the amount of polymeric residue present in the formation to be reduced.

Abstract: The invention describes improved environmentally friendly, non-toxic, CBM friendly, green fracturing compositions, methods of preparing fracturing compositions and methods of use. Importantly, the subject invention overcomes problems in the use of water-based mists as an effective fracturing composition particularly having regard to the ability of a mist to transport an effective volume of proppant into a formation. As a result, the subject technologies provide an effective economic solution to using high ratio gas fracturing compositions that can be produced in a continuous (i.e. non-batch) process without the attendant capital and operating costs of current pure gas fracturing equipment.

Abstract: Disclosed is a filter cake removal composition, and method of use thereof, for use in a wellbore for controlled removal of a filter cake present in a target production zone. The filter cake removal composition includes hydrochloric acid and an organic acid. The filter cake removal composition, when a mixture of the hydrochloric acid and the organic acid is applied to the filter cake in the target production zone, is operable to dissolve the filter cake in the target production zone over an extended reaction time. The mixture includes the hydrochloric acid present in an amount of between about 0.1% and 5% by weight and the organic acid present in an amount of between about 0.1% and 10% by weight.

Abstract: The use of a solvent for bitumen extraction, either from mined oil sands or in situ. The solvent includes (a) a polar component, the polar component being a compound comprising a non-terminal carbonyl group; and (b) a non-polar component, the non-polar component being a substantially aliphatic substantially non-halogenated alkane. The solvent has a Hansen hydrogen bonding parameter of 0.3 to 1.7 and/or a volume ratio of (a):(b) in the range of 10:90 to 50:50.

Abstract: A method for breaking the viscosity of an aqueous fluid gelled with a viscoelastic surfactant (VES) is disclosed. The method includes providing an aqueous fluid and adding to the aqueous fluid, in any order: at least one VES comprising a non-ionic surfactant, cationic surfactant, amphoteric surfactant or zwitterionic surfactant, or a combination thereof, in an amount sufficient to form a gelled aqueous fluid comprising a plurality of elongated micelles and having a viscosity, and a plurality of metallic particles to produce a mixture comprising dispersed metallic particles dispersed within the gelled aqueous fluid. The method also includes dissolving the metallic particles in the gelled aqueous fluid to provide a source of at least one transition metal ion in an amount effective to reduce the viscosity.

Abstract: A method for degrading a downhole article includes exposing the downhole article comprising a controlled electrolytic material to a composition that comprises a reducing agent. The method also includes contacting the downhole article with the reducing agent to degrade the downhole article. Additionally, a composition for degrading a downhole article includes water, chelant, metal ions, and a reducing agent that includes ascorbic acid, erythorbic acid, a derivative thereof, a salt thereof, or a combination thereof.

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: Aqueous treating fluids may include a viscoelastic surfactant (VES) and an aqueous base fluid, e.g. a drilling fluid, whereby the VES may increase and/or maintain the viscosity of the aqueous treating fluid. Metal ions may be present within the aqueous treating fluid that break, reduce, and/or digest the VES within the aqueous treating fluid. An effective amount of complexation particles may be added to the aqueous treating fluid for complexing at least a portion of these metal ions and thereby disallowing the metal ions from breaking, reducing, and/or altering the VES within the aqueous treating fluid.

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

Abstract: An aqueous buffered treatment solution for removing mud cake from a well bore treatment site is made by inducing an elevated temperature in an aqueous pre-buffer solution. The aqueous pre-buffer solution is made of an acid precursor that hydrolyzes into a treatment acid, a conjugate base salt that forms the conjugate base of the acid, and an aqueous fluid. Inducing the elevated temperature forms the treatment acid. The treatment acid is operable to remove mud cake. A method for removing a portion of mud cake from a treatment site using an aqueous buffered treatment solution to establish flow-back includes the step of introducing the aqueous pre-buffer solution to the treatment site. The introduction occurs such that the pre-buffer solution fluidly contacts the mud cake. The hydrocarbon-bearing formation induces the elevated temperature in the solution. Reaction between treatment acid and the acid-reactive constituents removes a portion of the mud cake.

Abstract: According to one aspect of the inventions, emulsion compositions are provided. Emulsions according to this aspect include: (a) a water-insoluble resinous material; (b) water; and (c) an emulsifier, wherein the emulsifier comprises a non-ionic, a cationic, or a zwitterionic emulsifier; wherein the continuous phase of the emulsion comprises the water; wherein a dispersed phase of the emulsion comprises the resinous material; wherein the dispersed phase is in the form of droplets having a size distribution range such that at least 50% of the droplets have a size of 0.5 micrometers-500 micrometers; wherein the resinous material of the droplets is in a concentration of at least 5% by weight of the water; and wherein the composition of the droplets has a viscosity of less than 2,000 Poise measured at 20° F. According to another aspect of the inventions, methods are provided for treating a portion of a subterranean formation.

Abstract: Systems and methods for processing glycerol into one or more useful products are provided. The method can include decreasing a pH of a mixture comprising glycerol and fatty acids to produce an emulsion comprising a glycerol-rich portion and a fatty acids-rich portion. At least a portion of the glycerol-rich portion can be reacted with at least one of an oxidant and a catalyst at conditions sufficient to produce a reacted product comprising glyceric acid, oxalic acid, glycolic acid, formic acid, or any combination thereof.

Abstract: Proppants for use in fractured or gravel packed/frac packed oil and gas wells are provided with a contaminant removal component to remove one or more of the contaminants found in subterranean water/hydrocarbon from a production well. The water/hydrocarbon cleaning proppant solids may be used as discrete particles in a proppant formulation, as a coating on proppant solids in pores of a porous proppant solid or as part of the proppant's internal structure. The contaminant removal component removes contaminants, especially dissolved contaminants, in the subterranean water or hydrocarbon before the water/hydrocarbon leaves the well. For those contaminant removal components that can be regenerated, such as ion exchange resins, a measured quantity of an acidic regeneration solution can be injected into the fractured stratum for regeneration and recovered when the well resumes production.

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: A method and apparatus for treating a subterranean formation traversed by a wellbore including forming an emulsion comprising oil, acid, and particulate, wherein the forming the emulsion is prepared on the fly, and introducing the emulsion into a wellbore.

Abstract: Methods and compositions for breaking treatment fluids utilized in the stimulation of a subterranean formation.

Abstract: Liquid hydrocarbons are gelled by the introduction of a phosphate ester and a crosslinking agent for use in oil recovery. Generally a proppant, delayed gel breaker and other modifiers are added to the gelled hydrocarbon to improve the oil recovery process. The phosphate ester used in this method and composition for oil recovery has low volatility and good stability during hydrocarbon distillation resulting in improved distillation efficiency in a refinery.