Abstract: A method of performing a squeeze treatment comprises pumping a treatment fluid under pressure through a wellbore into a subterranean formation, wherein the treatment fluid includes a hydrogen sulfide scavenging compound that adsorbs onto the subterranean formation in a region around the wellbore. Production fluids are then allowed to flow from the subterranean formation into the wellbore, wherein the production fluids contact the adsorbed hydrogen sulfide scavenging compound as the production fluids flow through the region around the wellbore, and wherein the production fluids contain hydrogen sulfide that reacts with the hydrogen sulfide scavenging compound to reduce an amount of hydrogen sulfide in the production fluids before the production fluids flow into the wellbore.

Abstract: Functionalized alpha-hydroxy alkyl ethers have been found to perform as non (or anti-) scaling hydrogen sulfide scavengers. A method of scavenging hydrogen sulfide includes contacting a fluid containing hydrogen sulfide with a treatment fluid including a functionalized alpha-hydroxy alkyl ether. Accordingly, the alpha-hydroxy alkyl ether reacts with the hydrogen sulfide to reduce the amount of hydrogen sulfide in the fluid. The functionalized alpha-hydroxy alkyl ether is functionalized with a phosphate group, phosphonate group, sulfate group, or sulfonate group. A broad range of alpha-hydroxy alkyl ethers are disclosed.

Abstract: Alpha-hydroxy alkyl esters have been found to perform as hydrogen sulfide scavengers. A method of scavenging hydrogen sulfide includes contacting a fluid containing hydrogen sulfide with a treatment fluid including an alpha-hydroxy alkyl ester. Accordingly, the alpha-hydroxy alkyl ester reacts with the hydrogen sulfide to reduce the amount of hydrogen sulfide in the fluid. A broad range of alpha-hydroxy alkyl esters are disclosed.

Abstract: Low dosage naphthenate inhibitors, such as a surfactant or hydrotrope, delivered into production fluids for contact with mixtures of oil and water, such as in a hydrocarbon producing formation, production equipment, or processing systems. Inhibitor compounds such as monophosphate esters and diphosphate esters exhibit surface-active properties that cause the inhibitors to self-associate at oil-water interfaces and inhibit interactions between organic acids in the oil with cations or cation complexes in the water. These compounds also inhibit aggregation of organic acid carboxylate salts that form when pH and pressure conditions are amenable to organic acid ionization. Preferred inhibitors do not form emulsions due to the formation of unstable mixed interface structures that result in coalescence of dispersed droplets.

Abstract: Inhibiting naphthenate salts that can form precipitates or emulsions during crude oil production or processing. An effective amount of a naphthenate inhibitor, such as a hydrotrope, is provided into the production fluids for contact with mixtures of oil and water in the formation, the production equipment, or processing systems. It is believed that the naphthenate inhibitors, such as monophosphate ester or diphosphate ester, exhibit surface-active properties that cause the inhibitors to align and concentrate in a layer at the oil-water interface and thereby prevent interactions between organic acids in the oil phase with cations or cation complexes in the water. It is believed that the physical positioning and geometry of the naphthenate inhibitor blocks the growth of naphthenate salt crystals. However, it is preferred that the naphthenate inhibitors also avoid the formation of oil-in-water and water-in-oil emulsions.

Abstract: A method and an amide composition used therein for inhibiting, retarding, mitigating, reducing, controlling and/or delaying formation of hydrocarbon hydrates or agglomerates of hydrates. The method may be applied to prevent or reduce or mitigate plugging of conduits, pipes, transfer lines, valves, and other places or equipment where hydrocarbon hydrate solids may form under the conditions. At least one amide compound is added into the process stream, where the compound may be mixed with another compound selected from amino alcohols, esters, quaternary ammonium, phosphonium or sulphonium salts, betaines, amine oxides, other amides, simple amine salts, and combinations thereof.

Abstract: A method for quantitative evaluation of emulsion stability using Critical Electric Field (CEF) determinations over a range of conditions, such as a range of temperatures, demulsifier compositions, or demulsifier concentrations. The method includes determining the CEF for a series of emulsions that differ substantially only in their internal phase volume ratio. A plot of CEF values as a function of the inverse of the internal phase volume ratio is characterized by a linear slope. Using the slope, a theoretical CEF value can be determined by extrapolating to where the inverse of the internal phase volume ratio is about one. The slope for a given emulsion series is associated with the relative energy barrier to flocculation and the theoretical critical electric field for a given emulsion series is associated with the relative energy barrier to coalescence. Comparative studies are performed using this method.

Abstract: A method and a quaternary ammonium or phosphonium composition used therein for inhibiting retarding, mitigating, reducing, controlling and/or delaying formation of hydrocarbon hydrates or agglomerates of hydrates. The method may be applied to prevent or reduce or mitigate plugging of conduits, pipes, transfer lines, valves, and other places or equipment where hydrocarbon hydrate solids may form under the conditions. At least one quaternary ammonium or phosphonium compound is added into the process stream, where the compound may be mixed with another compound selected from other amino alcohols, esters, quaternary ammonium, phosphonium or sulphonium salts, betaines, amine oxides, amides, simple amine salts, and combinations thereof.

Abstract: A method of reducing hydrolysis in a hydrocarbon stream comprising adding to a hydrocarbon stream containing a chloride compound which undergoes hydrolysis at elevated temperatures in the presence of water to form hydrochloric acid, an effective amount of a treating agent that is at least one overbased complex of a metal salt and an organic acid complexing agent, the treating agent being added to hydrocarbon stream when the stream is at a temperature below which any substantial hydrolysis of the chloride containing compound occurs.

Abstract: A method of treating hydrotest water to inhibits oxygen corrosion, microbiologically influenced corrosion (MIC) and to allow safe discharge of water. The combination treatment plan reduces biocide usage in a high pH brine. The reduced overall chemical usage facilitates meeting environmental guidelines while also minimizing chemical cost. The method includes: adding an oxygen scavenger to remove oxygen and prevent or minimize oxygen corrosion; raising the hydrotest water pH, typically in excess of pH 9.5; adding a biocide in reduced amount; and adding a scale inhibitor to inhibit scale.

Abstract: A low toxic, biodegradable, water soluble and dispersant series of corrosion inhibitors are described. The method of inhibiting corrosion in aqueous medium by incorporating the inhibitor in PPM is provided. The corrosion inhibitor compromises an acrylic acid and chloroacetic acid adduct of 2-substituted imidazolines or primary, secondary or tertiary amines with carbon chain of twelve to twenty-two saturated or unsaturated carbon atoms. The molar ratio of acrylic acid to chloroacetic acid was methodically changed while keeping the concentration of imidazoline or the amine a constant. The product is made water soluble by raising the pH to 8-9 at the end of the synthesis by adding aqueous sodium hydroxide.

Abstract: A metal salt removal procedure for use with a crude oil flow is disclosed. A small amount of water, and a caustic in the range of 7-12 pH, and preferably 9-12 pH, are injected to form water bubbles surrounded by oil. An ethylene oxide reacted with polypropylene glycol at 350° F. or so yields a water soluble demulsifier added at the rate of a few ppm to the water in oil mix. The added reaction product, a polyol, enables metal salt isolation in the water.

Abstract: The present invention provides compositions of oil-soluble inhibitors suitable for use in inhibiting oil field scale formation. The compositions comprise an acid form of a known scale inhibitor and a tertiary alkyl primary amine. These compositions possess advantages over conventional compositions used for inhibiting oil field scale.

Abstract: The present disclosure is concerned with inhibiting corrosion in metal, usually steel, equipment which is exposed to oil field production flow including gases, oil, water, and sand. It is injected into the aqueous stream and carried with it to contact and coat the metal surfaces. It includes a corrosion inhibitor including at least one sulfur amine based on the equation:R--X(C.sub.2 H.sub.4 NZ).sub.n C.sub.2 H.sub.4 NYIn which R is a C12-36 hydrocarbon;X is an amide-CO--NH-- or 5 membered cyclic imidazoline ring;Z is H or Y; Y is SO.sub.2 ;and .sub.n is an integer from 1 to 8.

Abstract: A corrosion inhibitor comprising a dispersant, an imidazoline, an amide, an alkyl pyridine and a heavy aromatic solvent. The resultant blend effectively inhibits corrosion of flow lines containing low pH mixtures of hydrocarbons, water, and acid gases.

Abstract: A corrosion inhibitor comprising a dispersant, an imidazoline, an amide, an alkyl pyridine and a heavy aromatic solvent. The resultant blend effectively inhibits corrosion of flow lines containing low pH mixtures of hydrocarbons, water, and acid gases.

Abstract: The invention is an effective, easy to produce, and economical corrosion inhibitor which can be used in a variety of environments. The corrosion inhibitor of the present invention is the salt of certain tertiary amines. The corrosion inhibitor is the reaction product of one or more tertiary amines and certain carboxylic acids, preferably a mixture of mercaptocarboxylic and carboxylic acids.

Abstract: The present invention relates to blends of individual corrosion inhibitors with phosphate esters for protection of ferrous metals against attack by a corrosive environment. These blends are synergistically more effective than each of the individual corrosion inhibitors. The phosphate esters of the present invention are the reaction products of ethoxylated, propoxylated, or butoxylated alcohols or phenols with phosphating agents. Other corrosion inhibitors suitable for blending with the phosphate esters include fatty amines, poly amides, imidazolines, poly imidazolines, quaternary amines, poly quats and dimer, trimer, and polymeric acids. Phosphate esters may comprise any portion of the total amount of corrosion inhibitors in the blend, but the preferred concentration is from about 5 to about 50 weight percent phosphate ester. The corrosion inhibitor blends may be diluted to any concentration with solvents or other fluids as necessary for particular applications.

Abstract: The present invention relates to a specific type of phosphate ester that is as effective or more effective than corrosion inhibitors available in the past. In accordance with the invention, these corrosion inhibitors are highly effective alone or when blended with other specific compounds for protection of ferrous metals against attack by a corrosive environment. More particularly, the inhibitors of the present invention are the reaction products of ethoxylated, propoxylated, or butoxylated alcohols or phenols with phosphating agents.

Abstract: The present invention relates to a method and a solution for use in downhole drilling to reduce the torque necessary to rotate the drill string. The solution comprises a sulfonate according to the formula (RSO.sub.3).sub.x Me.sup.x, where R is selected from the group consisting of an alkyl group, an aryl group, an alkylaryl group, and mixtures thereof having a molecular weight between about 280 and about 650, x is the number of (RSO.sub.3) groups, and Me.sup.x is a metal ion having a valence x. The solution is pumped down a drill string as a slug in order to coat solids which accumulate in the well and allow them to be removed along with the drilling fluid.