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: Adding relatively low molecular weight water-soluble friction loss reduction polymers to an aqueous fluid gelled with a viscoelastic surfactant (VES) increases the critical generalized Reynold's number at which the Fanning friction factor increases and friction pressure starts to increase rapidly. The water-soluble polymeric friction loss reduction additives lower surface pumping pressure in VES-gelled fracturing fluids for a given pump rate, thus lowering hydraulic horsepower (HHP) requirements for pumping fluids downhole, e.g. for hydraulic fracturing or frac packing treatments of subterranean formations.

Abstract: Fluids viscosified with viscoelastic surfactants (VESs) may have their viscosities reduced (gels broken) by the direct or indirect action of a synergistic internal breaker composition that contains at least one first internal breaker that may be a mineral oil and a second breaker that may be an unsaturated fatty acid. The internal breakers may initially be dispersed oil droplets in an internal, discontinuous phase of the fluid. This combination of different types of internal breakers break the VES-gelled aqueous fluid faster than if one of the breaker types is used alone in an equivalent total amount.

Abstract: Composition and method for shortening the shear recovery time of cationic, zwitterionic, and amphoteric viscoelastic surfactant fluid systems by adding an effective amount of a co-gelling agent selected from triblock oligomeric compounds having hydrophilic (for example polyether) and hydrophobic (for example alkyl) portions. The co-gelling agent also increases fluid viscosity and very low co-gelling agent concentration is needed. Preferred surfactants are betaines and quaternary amines. The fluids are useful in oilfield treatments, for example fracturing and gravel packing.

Abstract: A nano-dispersion well servicing fluid is disclosed. The well servicing fluid is formulated with components comprising: nanoparticles comprising at least one material chosen from aluminum oxides, aluminum hydroxides, aluminum hydroxyoxides, zirconium oxides, zirconium hydroxides, zirconium hydroxyoxides, wherein the concentration of nanoparticles is greater than 0.5% by weight based on the total weight of the nano-dispersion well servicing fluid. The well servicing fluid also comprises an aqueous base continuous phase. Methods of employing the nano-dispersion to service a wellbore are also disclosed.

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: The invention relates to gemini surfactants of formula IA wherein A is a core derived from an organic polyhydroxy compound; R1 and R2 are each independently a hydrophobic group; and R3 and R4 are each independently a surfactant head group. Such surfactants can be used as components of fluids used in the petroleum industry or used in formulating cleansing compositions or detergent compositions.

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: The present invention relates to an additive, and its use for inhibiting nucleation, growth and agglomeration of gas hydrates by adding an effective amount of an inhibitor to a multiphasic mixture which tends to hydrate formation and consists of water, gas and optionally condensate, or to a drilling fluid which tends to form gas hydrates. Said inhibitor comprising dialkoxylated quaternary ammonium compounds of the formula 1 where R1, R2 are each independently radicals of the formulae -(A-O)n—(C)—CO—O—R5, R3 is C1- to C30-alkyl or C2- to C30-alkenyl, R4 is an organic radical which optionally contains heteroatoms and has from 1 to 100 carbon atoms, R5 is an alkyl or an alkenyl, n is a number from 1 to 20, A is an alkylene group, B is an alkylene group, C is a C1- to C6-alkylene group and X is an anion, are used as gas hydrate inhibitors.

Abstract: A method comprises providing a treatment fluid comprising an aqueous fluid, and a low-leakoff particulate, contacting a subterranean formation with the treatment fluid, and allowing the low-leakoff particulate to de-link so that at least a portion of the low-leakoff particulate enters the liquid phase.

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: Methods relating to the hydrolysis of water-hydrolysable materials are provided. In one embodiment, a method of treating at least a portion of a subterranean formation is provided, the method comprising: providing a water-hydrolysable material; introducing the water-hydrolysable material into a well bore penetrating the subterranean formation; providing a treatment fluid comprising an aqueous liquid and a water-miscible solvent; introducing the treatment fluid into the well bore so as to contact the water-hydrolysable material; and allowing the water-hydrolysable material to hydrolyze. Methods of completing a well also are provided.

Abstract: In one embodiment, the present invention provides a drilling fluid composition that comprises a surfactant-free emulsion comprising an oleaginous fluid, a fluid that is at least partially immiscible with the oleaginous fluid, and a non-surfactant polymeric emulsifier. In another embodiment, the present invention provides a method of treating a subterranean formation comprising providing a treatment fluid that comprises a surfactant-free emulsion, the surfactant-free emulsion comprising an oleaginous fluid, a fluid that is at least partially immiscible with the oleaginous fluid, and a non-surfactant polymeric emulsifier; and treating the subterranean formation.

Abstract: A method of decreasing the viscosity of a gelled organic-based fluid is disclosed. The method comprises combining an organic solvent, a gelling agent, and a metal crosslinker; forming the gelled organic-based fluid; and adding a chelating agent forming a complex with the metal to decrease the viscosity of the gelled organic-based fluid. The chelating agent may be chosen within nitrilotriacetic acid (NTA), citric acid; ascorbic acid, hydroxyethylethylenediaminetriacetic acid (HEDTA) or its salts, ethylenediaminetetraacetic acid (EDTA) or its salts, diethylenetriaminepentaacetic acid (DTPA) or its salts, phosphinopolyacrylate, thioglycolates, or a combination thereof.

Abstract: The present invention relates to processes for tertiary mineral oil production with the aid of a surfactant mixture and to the use of a surfactant mixture for tertiary mineral oil production by means of Winsor type III microemulsion flooding, by injecting a surfactant mixture through at least one aqueous injection borehole into a mineral oil deposit, and withdrawing crude oil from the deposit through at least one production borehole, wherein the surfactant mixture, for the purpose of lowering the interfacial tension between oil and water to <0.1 mN/m, comprises at least the following components: (a) one or more polycarboxylate(s) comprising at least 50 mol % of acrylic acid units and/or methacrylic acid units and/or maleic acid units and/or itaconic acid units or salts thereof, and (b) one or more anionic and/or nonionic surfactant(s).

Abstract: Many methods are provided including a method comprising: providing a surfactant gel having a first viscosity that comprises an aqueous base fluid and a surfactant; providing an ortho ester breaker; contacting the surfactant gel with the ortho ester breaker; allowing the ortho ester breaker to hydrolyze to produce an acid and an alcohol; and allowing the acid and/or the alcohol to interact with the surfactant gel so as to reduce the first viscosity of the surfactant gel to a second viscosity.

Abstract: The present invention provides drilling fluids that comprise a base fluid and a water-soluble relative permeability modifier. In addition, the present invention provides methods of reducing the permeability of a subterranean formation to aqueous-based fluids during the drilling phase that comprises providing a water-soluble relative permeability modifier; and placing the water-soluble relative permeability modifier into the subterranean formation during the drilling phase. The present invention provides methods of drilling a well bore in a subterranean formation comprising providing a drilling fluid that comprises a base fluid and a water-soluble relative permeability modifier, and placing the drilling fluid in the subterranean formation. The water-soluble relative permeability modifiers of the present invention generally may comprise hydrophilically modified polymers, hydrophobically modified polymers, or water-soluble polymers without hydrophobic or hydrophilic modification.

Abstract: The present invention relates to a process for preparing ether carboxylates.

Abstract: An aqueous composition for treating hydrocarbon wells contains (a) a scale inhibitor and (b) a viscoelastic surfactant, and further contains from 0 to less than 1% by weight of acid selected from the group consisting of hydrochloric acid, sulfuric acid, phosphoric acid, formic acid, acetic acid, citric acid, maleic acid, hydrofluoric acid, and mixtures thereof.

Abstract: An aqueous fluid system that contains an aqueous dicarboxylic acid solution, a viscoelastic surfactant as a gelling agent to increase the viscosity of the fluid, and an internal breaker such as mineral oil and/or fish oil to controllably break the viscosity of the fluid provides a self-diverting acid treatment of subterranean formations. The internal breaker may be at least one mineral oil, a polyalphaolefin oil, a saturated fatty acid, and/or is an unsaturated fatty acid. The VES gelling agent does not yield viscosity until the organic acid starts to spend. Full viscosity yield of the VES gelling agent typically occurs at about 6.0 pH. The internal breaker allows the VES gelling agent to fully viscosify the spent organic acid at 6.0 pH and higher, but as the spent-acid VES gelled fluid reaching reservoir temperature, controllable break of the VES fluid viscosity over time can be achieved.

Abstract: A microemulsion system is disclosed which comprises a solvent subsystem, a co-solvent subsystem and a surfactant subsystem comprises at least one monoalkyl branched propoxy sulfate anionic surfactant, where the microemulsion system are useful in drilling, producing, remediation, and fracturing application to reduce water blocks and water blocking in formation of a producing formation.

Abstract: This relates to a method and composition for forming and utilizing a fluid in the oilfield services industry including exposing a polyacid and/or polyacid derivative to a preparation method, introducing the prepared polyacid and/or polyacid derivative to a fluid to form a treatment fluid, and treating a subterranean formation and/or a wellbore with the treatment fluid, wherein the viscosity of the treatment fluid is not observably reduced by introducing the prepared polyacid and/or polyacid derivative to a treatment fluid. This also relates to a method and composition for use in the oil field services industry including a prepared polyacid and/or polyacid derivative, a fluid, and a viscosity control agent, wherein the viscosity of the composition is not observably lower than if the prepared polyacid and/or polyacid derivative were not present.

Abstract: Hydrocarbon fluid compositions comprising a liquid hydrocarbon, an aluminum soap, a hydrocarbon foaming agent and a gas. The fluids can be used in various oil field operations.

Abstract: A process for making a coated substrate that includes treating a proppant with a coating agent, wherein the coating agent comprises at least one of monomeric alpha-hydroxycarboxylic acids, alpha-hydroxycarboxylic acid polymers, and combinations thereof, reacting the treated proppant to form a polymer coated proppant, and recovering the polymer coated proppant is disclosed.

Abstract: A process is described for replacing at least a portion of the liquid within the annular volume of a casing system within a wellbore with a second liquid. The second liquid is preselected to provide a measure of control of the pressure within the annular volume as the fluid within the volume is being heated.

Abstract: A method for treating a subterranean formation includes forming a treatment fluid including a carrier fluid, a solid acid-precursor, and a solid scale inhibitor. The solid acid-precursor includes a material that forms an acid at downhole conditions in the subterranean formation. The method further includes adding a solid acid-responsive material into the treatment fluid, where the solid acid-responsive material enhances formation of acid from the solid acid-precursor in acidic conditions. The method includes performing an acid fracture treatment and inhibiting scale formation within the subterranean formation. The solid scale inhibitor allows for long-term scale inhibition after the treatment.

Abstract: An acidizing fluid for sandstone formations is provided, along with methods of acidizing a sandstone formation penetrated by a wellbore. The aqueous acid treatment is a mixture of an aqueous liquid, a fluoride source, and an effective amount of at least one homopolymer or copolymer of a polycarboxylic acid, salt thereof or derivative thereof, which is introduced into the wellbore, and allowed to acidize the formation and concurrently inhibit calcium fluoride formation and impart calcium tolerance to the fluid.

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: The invention is directed to methods for treating a portion of a well. The methods include the steps of: (A) forming a viscoelastic treatment fluid, wherein the treatment fluid comprises: (i) water; (ii) a viscoelastic surfactant (“VES”), wherein the VES is soluble in the water and wherein the VES is in the form of micelles; and (iii) a cross-linking agent for the VES molecules, wherein: (a) the cross-linking agent comprises cross-linking agent molecules having at least one complexed transition metal, wherein the transition metal has a valence state of at least three; and (b) the cross-linking agent is soluble in the water; and (B) introducing the treatment fluid into a portion of the well. According to a first aspect of the invention, (a) the VES comprises VES molecules having an alkyl group of greater than 14 carbon atoms and (b) the VES comprises VES molecules having at least one functional group selected from a carboxylate group, an amino group, an alcohol group, and an ether group.

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: The invention discloses a method of treating a subterranean formation of a well bore: providing a treatment fluid made of: a fluid; a particulate material, and a viscosifier material; wherein the viscosifier material is inactive in a first state and is able to increase viscosity of the treatment fluid when in a second state; introducing the treatment fluid into the wellbore; and providing a trigger able to activate the viscosifier material from first state to second state.

Abstract: An aqueous composition for treating hydrocarbon wells contains (a) a scale inhibitor and (b) a viscoelastic surfactant, and further contains from 0 to less than 1% by weight of acid selected from the group consisting of hydrochloric acid, sulfuric acid, phosphoric acid, formic acid, acetic acid, citric acid, maleic acid, hydrofluoric acid, and mixtures thereof.

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 method of acidizing and cleaning up a formation is disclosed, the formation being above 150 degrees C. The formation is treated with a mutual solvent system comprising a mutual solvent of oil and water, an aqueous acid, a corrosion inhibitor, and an iron control agent. In some embodiments, the iron control agent is present in an amount of less than 1% by weight of the mutual solvent system. In some embodiments, the corrosion inhibitor may be present in an amount of less than 10% by weight of the mutual solvent system. In some embodiments, the mutual solvent system further comprises an intensifier.

Abstract: The invention relates to polymers with a mean molecular weight of between 500 and 500,000 g/mol that can be produced as follows: A) reaction of a compound of formula 1, in which n stands for 0, 1 or 2 and A for an arbitrarily substituted C1-C40 group with a compound of the formula 2 B(OH)m in which m is from 2 to 10 and B is a represents an arbitrarily substituted C2-C40 group, B) subsequently reaction of the product thus obtained with a nitrogen-containing carboxylic acid which comprises from 1 to 20 carbon atoms, where the molar ratio between the number of free OH groups of the polyester obtained in step A and the nitrogen-containing carboxylic acid is between 1:0.1 and 1:1. The polymers are used to inhibit gas hydrate formation.

Abstract: The systems and methods described herein provide for modified lignins and other compositions that may be useful as surfactants. These compositions have particular utility for energy-related applications. In embodiments, they may be useful for enhanced oil recovery. In embodiments, they may be useful for extracting bitumen from oil sands. In embodiments, they may be useful for environmental remediation.

Abstract: A powder composition comprising viscoelastic surfactant forms, in aqueous solution, a viscoelastic wellbore treatment fluid.

Abstract: A treatment of a subterranean formation which contains a hydrocarbon-bearing zone, is carried out using a hydrocarbon-responsive fluid thickened with an oligomeric surfactant consisting of from 2 to 8_linked surfactant monomer subunits. The process of treatment comprises (i) mixing a thickening amount of oligomeric surfactant with an aqueous liquid to make a viscoelastic treatment fluid, (ii) pumping said viscoelastic treatment fluid through a wellbore and into the subterranean formation, where (iii) contact with hydrocarbons within the formation dissipates the viscosity of the treatment fluid.

Abstract: A new class of winterizing compositions are disclosed including a winterizing agents being a compound of general formula Z(R1)m, where Z is a polyol having between 5 and 30 carbon atoms, R1 is a carbyl group having between about 10 and about 40 carbon atoms, and where m is an integer having the value of 1 or 2, when m is 2, R1 can be the same or different and one or more carbon atoms of R1 can be replaced by B, N, O, Si, P, S, Ge and/or mixtures thereof and one or more of the hydrogen atoms in R1 can be replaced by F, Cl, Br, I, CONR22, COOR2, OR2, NR22, SR2, PR22, and/or mixtures thereof and where R2 can be a hydrogen atom, alkyl, aryl, alkylaryl or arylalkyl group having between 1-20 carbon atoms where one or more carbon or hydrogen atoms can be replaced as set forth for R1.

Abstract: The present invention relates to acidic treatment fluids that comprise an acid fluid and an ester-containing quaternary ammonium compound (“esterquat”) and methods of their use. One embodiment of the present invention provides a method of inhibiting metal corrosion during a subterranean treatment operation comprising using an acidic treatment fluid comprising an acidic fluid and an esterquat. Another embodiment of the present invention provides a method of reducing sludge formation during a subterranean treatment operation formation comprising the step of using an acidic treatment fluid comprising an acidic fluid and an esterquat. Another embodiment of the present invention provides a method of inhibiting the formation of emulsions during a subterranean treatment operation comprising using an acidic treatment fluid comprising an acidic fluid and an esterquat. Another embodiment of the present invention provides an acidic subterranean treatment fluid comprising an acidic fluid and an esterquat.

Abstract: Exemplary embodiments of the cement compositions comprise water, a cement, and a fluid loss control additive, the fluid loss control additive comprising a graft copolymer. The graft copolymer comprises a backbone and at least four grafted monomers selected from the group consisting of 2-acrylamido-2-methylpropanesulfonic acid, acrylamide, acrylic acid, vinylphosphonic acid, diallyldimethylammonium chloride, and salts thereof. The backbone of the graft copolymer comprises a humic acid salt. Methods of cementing using exemplary embodiments of the cement compositions are also provided.

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: 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: Piezoelectric crystal particles (which include pyroelectric crystal particles) enhance the viscosity of aqueous fluids that have increased viscosity due to the presence of viscoelastic surfactants (VESs). In one non-limiting theory, when the fluid containing the viscosity enhancers is heated and/or placed under pressure, the particles develop surface charges that associate, link, connect, or relate the VES micelles thereby increasing the viscosity of the fluid. The higher fluid viscosity is beneficial to crack the formation rock during a fracturing operation, reduce fluid leakoff, and carry high loading proppants to maintain the high conductivity of fractures.

Abstract: A process that includes pumping a first wellbore fluid comprising an oxidative degradable polymer into a wellbore through a subterranean formation; pumping a second wellbore fluid comprising a pH-activated oxidative breaker into the wellbore; pumping a third wellbore fluid comprising a delayed acid source into the wellbore; and allowing the delayed acid source to acidify at least a portion of the wellbore to a pH of less than 7 so as to activate the pH-activated oxidative breaker at the lower pH and degrade the oxidative degradable polymers is disclosed.

Abstract: Fluids viscosified with viscoelastic surfactants (VESs) may have their viscosities reduced (gels broken) by the direct or indirect action of a synergistic internal breaker composition that contains at least one first internal breaker that may be a mineral oil and a second breaker that may be an unsaturated fatty acid. The internal breakers may initially be dispersed oil droplets in an internal, discontinuous phase of the fluid. This combination of different types of internal breakers break the VES-gelled aqueous fluid faster than if one of the breaker types is used alone in an equivalent total amount.

Abstract: An aqueous fluid system that contains an aqueous dicarboxylic acid solution, a viscoelastic surfactant as a gelling agent to increase the viscosity of the fluid, and an internal breaker such as mineral oil and/or fish oil to controllably break the viscosity of the fluid provides a self-diverting acid treatment of subterranean formations. The internal breaker may be at least one mineral oil, a polyalphaolefin oil, a saturated fatty acid, and/or is an unsaturated fatty acid. The VES gelling agent does not yield viscosity until the organic acid starts to spend. Full viscosity yield of the VES gelling agent typically occurs at about 6.0 pH. The internal breaker allows the VES gelling agent to fully viscosify the spent organic acid at 6.0 pH and higher, but as the spent-acid VES gelled fluid reaching reservoir temperature, controllable break of the VES fluid viscosity over time can be achieved.

Abstract: A method of servicing a wellbore comprising preparing a composition comprising a calcium aluminate cement, water, a polyphosphate, a pozzolan, and a set retarding agent, wherein the set retarding agent comprises an alkali halide and a basic phosphate salt, placing the composition in the wellbore and allowing the composition to set. A composition comprising a calcium aluminate cement in an amount of from about 30 wt. % to about 60 wt. % and a set retarding agent in an amount of from about 0.1 wt. % to about 15 wt. % based upon the total weight of the composition, wherein the set retarding agent comprises an alkali halide and a basic phosphate salt in a ratio of from about 3:1 to about 1:3.

Abstract: A method of treating a formation penetrated by a wellbore to reduce fluid loss to the formation is carried out by providing a quantity of water-degradable particles formed from a solid polymeric acid precursor having a number average molecular weight (Mn) of greater than 4000. A slurry of the particles is formed with a carrier fluid, which may be an aqueous fluid. The slurry is introduced into the formation through the wellbore at a pressure below the fracture pressure of the treated formation. A treating fluid is subsequently introduced into the formation through the wellbore. The water-degradable particles degrade by contacting the particles with a free aqueous fluid introduced into the formation through the wellbore. The water-degradable particles may have a particle size of from about 0.25 mm or less. The slurry may contain from about 0.01 kg/L to about 0.15 kg/L of the water degradable particles.

Abstract: A system includes a wellbore in fluid communication with a formation of interest and a fracturing slurry include a carrier fluid with a low amount of a viscosifier, an amount of proppant including a first average particle size between about 200 and 2000 ?m, an amount particulates including a second average particle size between about three and ten times smaller than the first average particle size, and a third amount of particulates having a third average particle size smaller than the second average particle size. A sum of all of the particulates in the fracturing slurry exceed about 16 pounds per gallon of the carrier fluid. They system further includes a pumping device that creates a propped fracture in the formation of interest with the fracturing slurry, and a removal agent that removes the second amount of particulates and/or the third amount of particulates from the propped fracture.