Abstract: A friction reducer comprising a copolymer of acrylamide, an anionic monomer, a zwitterionic monomer or a cationic monomer, a physical ligand or a chemical ligand, wherein the acrylamide amounts to at least 50% (w/w) of the total monomer content. The friction reducer is useful in hydraulic fracturing operations and is obtained by controlled radical polymerization at a temperature between 30° C. and 70° C. using iodine as polymerization control agent.

Abstract: Embodiments of the disclosure include swellable smart gel sealants and methods of using smart gel sealants. In certain embodiments, the smart gel sealants reversibly swell when exposed to a certain trigger, such as temperature or pH. In specific embodiments, the smart gel is disposed within voids in a well and triggered to swell in order to seal the voids. One application of the smart gel sealant is to seal the casing of a well against the leakage of gas, such as H2S.

Abstract: Provided are treatment fluids and associated methods for removing metal sulfate scale. An example method includes introducing a treatment fluid into a wellbore comprising metal sulfate scale, wherein the treatment fluid comprises: a phosphonated aminocarboxylate; a carboxylated alkanol, a carboxylated alkyl halide, and/or a multicarboxylic acid; an anion; and an aqueous base fluid; wherein the treatment fluid has a pH in a range between about 7 to about 13. The method further includes contacting the metal sulfate scale with the treatment fluid; wherein the treatment fluid is allowed to remain static during the contacting; and removing the treatment fluid from the wellbore.

Abstract: The present disclosure relates to acidizing treatment fluids for use in subterranean formation, such as wellbore, operations for dissolving iron sulfide scale, such as iron sulfide scale in sour conditions. Such treatment fluids comprise an aqueous base fluid; an acid; a chelating agent of methylglycine diacetic acid trisodium salt; and a hydrogen sulfide scavenger blend comprising 3-hydroxybutanal, crotonaldehyde, acetaldehyde, and a solvent base fluid.

Abstract: Methods and systems for protecting acid-reactive surfaces, particularly during subterranean treatment operations in which acids are used. In some embodiments, the methods include: providing a fluid additive including an organic compound and a base, wherein the organic compound includes a phosphonoalkyl moiety; providing an acid or acid generating source; mixing at least the fluid additive and the acid or acid generating source to form a treatment fluid; and introducing the treatment fluid into at least a portion of a subterranean formation.

Abstract: A method for cleaning a surface of an aluminum or aluminum alloy body by immersing the surface in a basic aqueous electrolyte formed essentially from dissolved trisodium phosphate, flowing DC current through the electrolyte and the body for cleaning, and then removing the body from the electrolyte. An additional cleaning step, which may include ultrasonic cleaning, may be performed to remove loose matter adhering to the body after the electrolytic cleaning.

Abstract: On-line diverting acids for continuous injection into water injection wells and methods of preparing the diverting acid are disclosed. The on-line diverting acids have a raw material composition of: 5.0-25.0% of hydrochloric acid, 3.0%-6.0% of ammonium fluoride, 4.0%-8.0% of a diverting agent, 3.0%-7.0% of a chelating agent, 1.0-3.0% of a corrosion inhibitor, 1.0-3.0% of an anti-swelling/swelled-clay-shrinking agent and a balance of water. The on-line diverting acids can remove plugging from deep zones of high and low permeability layers, and can be continuously injected to simplify the construction process, to achieve the purpose of reducing the pressure and stimulating the injection.

Abstract: A synthetic caustic composition for use in oil & gas industry activities, said composition comprising: metal hydroxides; an amino acid; urea; a sodium silicate and water.

Abstract: Gas fracturing methods and systems utilizing a gas treatment fluid, which may contain a dispersed phase of fluid loss control agent particles. Also, treatment fluids suitable for use in the methods and systems are disclosed.

Abstract: Included are methods and systems for drilling in a subterranean formation. A method comprises providing a drilling fluid comprising an aqueous base fluid and a betaine shale stabilizer; placing the drilling fluid into the subterranean formation; and drilling a wellbore in the subterranean formation. A drilling system comprises a drilling fluid comprising an aqueous base fluid and a betaine shale stabilizer; a drilling assembly; a drill string coupled to the drilling assembly; a pumping system fluidically coupled to the drill string, wherein the pumping system is capable of pumping the drilling fluid through the drill string.

Abstract: Chelating agents may be used to mitigate the presence of metal ions in a subterranean formation, thereby decreasing the likelihood of the metal ions forming damaging insoluble compounds within the subterranean formation. Methods for treating a subterranean formation can comprise: providing a treatment fluid comprising an aqueous carrier fluid and a chelating agent comprising hydroxyiminodisuccinic acid or any salt thereof; introducing the treatment fluid into a subterranean formation comprising a carbonate mineral; and complexing a metal ion in the subterranean formation with the chelating agent.

Abstract: Alkali metal ions may lead to the production of insoluble materials during the course of stimulating a subterranean formation, particularly when acidizing a siliceous formation or a formation containing a siliceous material. Alkali metal ions may be sequestered using an alkali metal complexing agent in order to reduce their propensity toward forming insoluble materials in a subterranean formation. Methods for stimulating a subterranean formation can comprise: providing a treatment fluid that comprises an alkali metal complexing agent comprising a cyclic polyether having between 3 and 6 ether oxygen atoms present therein, and hydrofluoric acid, a hydrofluoric acid-generating compound, or any combination thereof; and introducing the treatment fluid into a subterranean formation.

Abstract: The present invention relates to a composition containing a dispersed phase emulsified in a continuous phase, wherein at least 5 wt % on total weight of the dispersed phase of the composition is a chelating agent selected from the group of glutamic acid N,N-diacetic acid or a salt thereof (GLDA), aspartic acid N,N-diacetic acid or a salt thereof (ASDA), and methylglycine N,N-diacetic acid or a salt thereof (MGDA), and a process for treating a subterranean formation comprising a step of introducing the above composition into the 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: Aqueous compositions contain hydrochloric acid at a concentration between 8 wt % and 28 wt % inclusive. The amino acid; hydrochloric acid mole ratio may be between 0.2 and 1.5. Sufficient water is present to dissolve the hydrochloric acid and the amino acid. Such compositions have utility as retarders for acid compositions employed in the stimulation of subterranean formations. Slowing the reaction between the acid and formation helps maximize formation permeability and productivity.

Abstract: Provided herein are inter alia novel compositions and methods having application in a variety of fields including the field of enhanced oil recovery, the cleaning industry as well as groundwater remediation. In particular, the alkoxy carboxylate compounds and mixtures thereof presented herein can be used, inter alia, for the recovery of a large range of crude oil compositions from challenging reservoirs.

Abstract: Methods and compositions including a method comprising: providing a treatment fluid comprising an aqueous fluid, a relative permeability modifier, and a chelating agent; introducing the treatment fluid into a well bore that penetrates a subterranean formation; and allowing at least a first portion of the treatment fluid to penetrate into a portion of the subterranean formation so as to substantially divert a second portion of the treatment fluid to another portion of the subterranean formation.

Abstract: A method of gravel packing a hole in a subterranean formation having a filter cake coated on the surface thereof that includes injecting into the hole a gravel pack composition comprising gravel and a carrier fluid comprising a base fluid and at least one iminodiacetic acid or salt thereof is disclosed.

Abstract: Methods of preventing precipitation of calcium citrate and iron-based scale during acidizing treatments and related compositions are provided as embodiments of the present invention. The acidizing treatment fluid includes citric acid and tetra-salts of EDTA.

Abstract: The chelating fluid for enhanced oil recovery in carbonate reservoirs and the method of using the same utilizes a chelating fluid injected into a carbonate oil reservoir through a fluid injection system. The chelating fluid is a solution of a polyamino carboxylic acid chelating agent in brine, with the polyamino carboxylic acid chelating agent having a concentration of approximately 5.0 wt % of the solution, with the solution having a pH of approximately 11.0. The polyamino carboxylic acid chelating agent is preferably ethylenediaminetetraacetic acid (EDTA). The brine preferably has a relatively high salinity, with a sodium chloride concentration preferably on the order of approximately 18,300 ppm.

Abstract: When used outside the pH range at which metal ion complexation normally occurs, aminopolycarboxylic acids can moderate the reaction rate of acids with carbonate minerals. Methods for treating a subterranean formation can comprise: providing a treatment fluid comprising an aqueous carrier fluid, an acid, and a chelating agent comprising an aminopolycarboxylic acid, the treatment fluid having a pH below that at which the carboxylic acid groups of the chelating agent are substantially protonated and the chelating agent is ineffective for complexing a metal ion; introducing the treatment fluid into a subterranean formation comprising a carbonate mineral; reacting the acid with the carbonate mineral, such that the acid at least partially spends and the pH of the treatment fluid rises; and once the pH of the treatment fluid rises above a pKa value for one or more of the carboxylic acid groups, complexing a metal ion with the chelating agent.

Abstract: Biphenylmono- and polysulphonic acids and salts thereof, fluorenemono- and polysulphonic acids and salts thereof as well as p-terphenylmono- and polysulphonic acids and salts thereof may be used successfully as tracers for surveying, monitoring and/or measuring movements of aqueous fluids in aqueous and/or non-aqueous media. Said substances are especially suited for surveying or monitoring movements of fluids in oil wells or reservoirs as well as for fluid movements in hydrothermal reservoirs.

Abstract: Compositions of and methods of using a fluid formulation for increasing flow, production, and/or recovery of oil and gas hydrocarbons from a subterranean formation.

Abstract: This invention relates to a process for inhibiting scaling in a subterranean oil or gas producing formation, comprising adding to the formation a composition comprising a metal chelant, a scale inhibitor and divalent metal cations, wherein the stability constant of the metal chelant—metal cation chelate at ambient temperature is equal to or higher than the stability constant of the chelate formed from the metal cations and the scale inhibitor, and wherein the solubility of the chelate formed from the metal cations and the scale inhibitor decreases with increasing temperature.

Abstract: The present invention relates to processes for consolidating an underground formation with a consolidating mineral. The consolidating material is a carbonate and is produced from an alkaline treatment fluid containing, in at least some embodiments, environmentally friendly and inexpensive components. In one embodiment, the process can be applied to consolidation of an underground formation during or following drilling. The present invention also provides a treatment fluid suitable for use in such processes.

Abstract: A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising an amino multicarboxylic acid chelating agent, a pH adjusting compound, and an aqueous base fluid, and contacting the wellbore servicing fluid with scale deposits on a surface in fluid communication with the wellbore and/or subterranean formation.

Abstract: A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising an amino polyether multicarboxylic acid chelating agent and/or an amino polyether multicarboxylic acid chelating agent precursor, and an aqueous base fluid, and contacting the wellbore servicing fluid with scale deposits on a surface in the wellbore and/or subterranean formation. A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising an amino polyether multicarboxylic chelating agent precursor and an aqueous base fluid, and contacting the wellbore servicing fluid with scale deposits on a surface in the wellbore and/or subterranean formation. A scale-removing wellbore servicing fluid comprising an amino polyether multicarboxylic acid chelating agent and/or an amino polyether multicarboxylic acid chelating agent precursor, and an aqueous base fluid.

Abstract: Acidizing fluids may be formulated to minimize the detrimental effects of precipitation during an acidizing operation by promoting production of precipitates from a subterranean formation. Methods for acidizing a subterranean formation can comprise: providing an acidizing fluid comprising a stabilized microemulsion carrier fluid, a chelating agent, and an acid source; introducing the acidizing fluid into a subterranean formation; at least partially dissolving a surface in the subterranean formation with the acidizing fluid, thereby forming a spent fluid; and producing the spent fluid from the subterranean formation.

Abstract: This invention relates to a process for inhibiting scaling in a subterranean oil or gas producing formation, comprising adding to the formation a composition comprising a metal chelant, a scale inhibitor and divalent metal cations, wherein the stability constant of the metal chelant-metal cation chelate at ambient temperature is equal to or higher than the stability constant of the chelate formed from the metal cations and the scale inhibitor, and wherein the solubility of the chelate formed from the metal cations and the scale inhibitor decreases with increasing temperature.

Abstract: Stabilizers that include hydrophobically modified amine-containing polymers may be utilized as compositions or in methods for controlling particulate migration in a subterranean formation. For example, a method may include providing a treatment fluid that comprises a base fluid and a hydrophobically modified amine-containing polymer (HMAP), the HMAP comprising a plurality of hydrophobic modifications on an amine-containing polymer; introducing the treatment fluid into a wellbore penetrating a subterranean formation, the subterranean formation comprising a plurality of particulates; and allowing the HMAP to coat at least some of the particulates.

Abstract: A downhole fluid comprises a base fluid, for example a hydrocarbon base fluid, a gelling agent, and a gel enhancer. The gelling agent has an aromatic core of one or more aromatic rings, the gelling agent having two or more amide branches distributed about the aromatic core, each of the two or more amide branches having one or more organic groups. An example gelling agent is a pyromellitamide gelling agent. A method of making a downhole fluid, the method comprising: combining a base fluid, a gelling agent, and a gel enhancer. A downhole fluid comprising a base fluid, a gelling agent, a breaker, and a gel enhancer. Downhole fluids with such gels and a breaker are also disclosed.

Abstract: The invention provides for the use of 1-alkyl-5-oxopyrrolidine-3-carboxylic esters, preparable by esterifying alcohols having from 1 to 100 hydroxyl groups with 1-alkyl-5-oxopyrrolidine-3-carboxylic acid, in amounts of from 0.01 to 2% by weight for preventing the formation of gas hydrates in aqueous phases which are in contact with a gaseous, liquid or solid organic phase.

Abstract: The present invention relates to process to reduce the corrosion of equipment containing a chromium-containing alloy in the oil and/or gas industry, comprising a step of contacting the equipment based on a chromium-containing alloy with a solution containing at least 1 wt % on total weight of the solution of glutamic acid N,N-diacetic acid or a salt thereof (GLDA) and/or methylglycine N,N-diacetic acid or a salt thereof (MGDA) having an acidic pH, the use of the above solutions in equipment containing a chromium-containing alloy to reduce corrosion, and to a system containing a piece of equipment used in the oil and/or gas industry made at least partly from chromium-containing alloy in contact with an acidic solution containing at least 1 wt % of glutamic acid N,N-di acetic acid or a salt thereof (GLDA) and/or methylglycine N,N-di acetic acid or a salt thereof (MGDA).

Abstract: A method of servicing a wellbore in a subterranean formation comprising preparing an invert emulsion comprising an aqueous fluid, an oleaginous fluid, and an emulsifier composition (EC), wherein the emulsifier composition comprises an emulsifier, a diluent, and a thinner, wherein the thinner comprises an alcohol, a fatty acid amide, or combinations thereof; and placing the invert emulsion in the wellbore. A method of servicing a wellbore in a subterranean formation comprising flowing a wellbore serving fluid comprising an emulsifier composition (EC) through a portion of a subterranean formation, wherein the EC comprises an emulsifier, a diluent and a thinner and wherein the thinner comprises 2-methyl-1-propanol, 2-methyl-2-butanol, a fatty acid amide, or combinations thereof; contacting the EC with oil in situ within the formation to form an emulsion; and reducing the water-oil interfacial tension and altering the wettability to provide enhanced oil recovery from the formation.

Abstract: A substantially liquid gellant formed as one or more reaction products of a metal carboxylate or metal carboxylate amine salt, one or more organic acids, an ester which drives the reaction so that the reaction products are asymmetrical in structure, and a rheology modifier which preferentially interacts between the reaction products for prevent solidifying of the gellant reaction products until such time as the gellant is mixed with the fracturing fluid containing an activator after which the reaction products preferentially interact with the activator to gel the fracturing fluid. The resulting gellant is capable of gelling a hydrocarbon base fluid in less than about 30 seconds.

Abstract: The invention is directed to long lasting crosslinked water-soluble swellable polymers, methods for making same, and their uses. More particularly, the invention relates to a composition comprising expandable polymeric particles having cationic sites as well as labile crosslinkers and stable crosslinkers, said particle mixed with a fluid. A particularly important use is as an injection fluid in petroleum production, where the expandable polymeric particles are injected into a target zones in the reservoirs and when the heat and/or a suitable pH in the reservoir cause degradation of the labile crosslinker and when the particle expands, the cationic sites in the polymer adsorb to negative sites of the rock in the formation, thus diverting water to lower permeability regions and improving oil recovery. However, many other uses are possible.

Abstract: The invention relates to a class of novel surfactants that have utility in the recovery and/or extraction of oil.

Abstract: A variety of betaine esters, including dialkylaminoalkyl cocoate betaines and dialkylaminoalkyl hydrogenated cocoate betaines are disclosed. These betaines can be advantageously prepared in high yield and purity by a three-step transiterification chemoenzymatic process or a two-step direct esterficiation chemoenzymatic process. These betaine esters have excellent surfactant properties.

Abstract: The invention relates to the use of compounds comprising three hydrophobic groups as additives to a stream of crude oil containing carboxylic acids, in particular naphthenic acids, and salt water, to prevent the formation of calcium carboxylates when the fluid is exposed to shear forces. Preferably, the compounds are added to a crude oil/water stream containing organic acids Ca2+ ions at a point between the well and the pressure reduction valve in the crude oil receiving station.

Abstract: Melamine derivatives and mixtures thereof with aqueous systems, a process for inhibiting corrosion of metals and metal alloys with melamine derivatives and mixtures thereof and the use of melamine derivatives and mixtures thereof as corrosion inhibitors for aqueous systems, for example water/oil mixtures, especially in the field of cleaning compositions, cooling fluids, oilfield chemicals or lubricants.

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: The present invention relates to a chelating agent precursor that contains glutamic acid N,N-diacetic acid (GLDA) and/or methylglycine N,N-diacetic acid (MGDA) wherein at least one of the carboxylic acid groups is present as a carboxylic acid derivative selected from the group of amides, anhydrides, and esters, combinations thereof, and salts thereof, provided that it is not the triethyl ester of GLDA, the triethyl mono-t-butyl ester of GLDA, the tri-t-butyl ester of GLDA, the monobenzyl tri-t-butyl ester of GLDA, any ester or amide that contains azacycloalkane groups, any amide that contains biotin groups, any amide that contains minoethylcarbamoyl based amide groups, (S)-diethyl 2,2?-(1-benzyloxy)-1,5-dioxo-5-(prop-2-ynylamino)pentan-2-ylazanediyl-diacetate, diethyl 2,2?-(5-(3-azidopropylamino)-1-(benzyloxy)-1,5-dioxo-pentan-2-ylazanediyl-diacetate, the trimethyl ester of MGDA, the monomethyl ester dimethylamide of MGDA, the dibenzyl ester of MGDA, the dibenzyl mono t-butyl ester of MGDA, the di t-butyl est

Abstract: The composition and method for treating carbonate reservoirs provides a treatment fluid for the acid treatment of stratified subterranean formations. The treatment fluid is injected into a non-problematic or high permeability zone of a carbonate reservoir. The treatment fluid is formed from a zwitterionic viscoelastic surfactant, which forms about 7.5 vol % of the treatment fluid, hydrochloric acid forming about 15.0 vol % of the treatment fluid, and a corrosion inhibitor forming about 0.6 vol % of the treatment fluid, the balance being brine. The treatment fluid gels as the hydrochloric acid reacts with carbonate of the carbonate reservoir, thus forming a diverting block in the non-problematic or high permeability zone. Following formation of the diverting block, a further volume of the treatment fluid is injected into the carbonate reservoir. The diverting block diverts the treatment fluid into a problematic or low permeability zone of the carbonate reservoir.

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: Disclosed herein is a well treatment method comprising the steps of injecting into a well a fluid loss control agent comprising a chelating agent, a viscosity increasing agent, and a plurality of at least partially insoluble bridging solid particles dispersed therein, wherein the chelating agent is effective to at least partially solubilize at least a portion of the bridging solid particles over a solubilizing period of time for thereafter substantially dissolving the bridging solid particles, wherein the solubilizing period of time is controlled by the concentration of the viscosity increasing agent, the concentration of the chelating agent, the composition of the metal salt, the pH of the fluid loss control agent, or a combination thereof. A fluid loss control agent is also disclosed.

Abstract: The present invention relates to the application of geminals zwitterionics liquids based on bis-N-alkyl or bis-N-alkenyl or N-cycloalkyl or N-aryl bis-beta aminoacids or its salts thereof as wettability modifiers of rocks such as limestone, dolomite, sand, quartz or heterogeneous lithologies, in the presence of brines with high content of divalent ions such as calcium, magnesium, barium and strontium, high temperature and pressure in processes of enhanced oil recovery. Wettability modifier comprises a geminal zwitterionic liquid based on bis-N-alkyl or bis-N-alkenyl or N-cycloalkyl or N-aryl bis-beta aminoacids or its salts, using as solvent distilled or brine with a high content of divalent ions such as calcium and magnesium or organic solvents compounds derived from alcohols like methanol, ethanol, isopropanol or mixtures thereof, or aromatic as isomers of xylene, toluene, or diesel, gasoline or mixtures thereof.

Abstract: Disclosed herein are methods of using compositions as enhanced oil recovery agents, cleaning agents or as agents that improve the function of surfactants, the compositions comprising a surfactant and a protein system, where the protein system comprises proteins and stress proteins obtained by the process of fermenting yeast to obtain a fermentation mixture; subjecting the fermentation mixture to stress conditions to obtain a post-fermentation mixture; and centrifuging the post-fermentation mixture and obtaining the supernatant; where the protein mixture retains its functionality under extreme conditions.

Abstract: The present invention relates to a process for treating a subterranean formation wherein a fluid containing an ammonium salt of glutamic acid N, N-diacetic acid (GLDA) or methylglycine N, N-diacetic acid (MGDA) is introduced into the formation.

Abstract: The present invention relates to a process for treating a sandstone formation comprising introducing a fluid containing glutamic acid N,N-diacetic acid or a salt thereof (GLDA) and having a pH of between 1 and 14 into the formation. The invention in addition relates to a fluid and a kit of parts suitable for use in the above process containing glutamic acid N,N-diacetic acid or a salt thereof (GLDA), a corrosion inhibitor, a surfactant, and optionally a mutual solvent.

Abstract: The present invention relates to a process to control iron in a subterranean formation wherein a fluid containing glutamic acid N,N-diacetic acid or a salt thereof (GLDA) and/or methylglycine N,N-diacetic acid or a salt thereof (MGDA) is introduced into the formation at a temperature between 77 and 400° F. (about 2 and 204° C.). The invention also covers a process of treating a subterranean formation wherein simultaneously iron control takes place.