Abstract: A method of treating liquid, particularly an oil/water mixture, in an oil well pipe, wherein a radio frequency propagating electrical field is established in the liquid in the pipe cause the formation of seed crystals or scale-forming material in the liquid, on which seed crystals asphaltenes and/or paraffin waxes in the liquid are deposited so that they are carried through the pipe with the liquid in preference to being deposited on the pipe wall.

Abstract: An efficient truck-mounted injection system for injecting a combined aqueous or hydrocarbon-based liquid stream and a liquid carbon dioxide stream via a well into a subterranean formation.

Abstract: A fluid loss control method uses a fluid loss control pill in a well in advance of a completion operation. An embodiment of the fluid loss control pill comprises polyester solids that are hydrolysable and can exhibit plastic deformation at formation conditions. An embodiment of the method comprises spotting the fluid loss control pill in the well adjacent to a formation to form a filtercake to inhibit fluid entry from the well into the formation, performing a completion operation comprising contacting the filtercake with overbalanced wellbore fluid, and degrading the filtercake wherein the polyester particles are hydrolyzed to remove formation damage.

Abstract: Naphthenic acid solids and/or emulsions can be inhibited by introducing an additive to crude oil prior to or concurrent with the deprotonation of the naphthenic acids present in the crude oil. The additives may be surfactants and can be amines, quaternary ammonium compounds, quaternary phosphonium compounds, and mixtures of both. The additives may also be linear compounds having at least two carboxylic acid or acrylic acid functional moieties.

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 iron control agent capable of reducing ferric iron containing compounds to ferrous iron containing compounds in an acidic solution, such as one used for formation acidizing. The iron control agent comprises a combination of a sulfur dioxide, sulfurous acid, sulfite salts, bisulfite salts, or thiosulfate salts or mixtures thereof, with a source of copper ions and a source of iodine or iodine ions. The iron control agent may also include small amounts of an adjunct such as stannous chloride, 2-mercaptoethanol, and thioglycolic acid and its salts.

Abstract: The invention relates to cleaning wellbores and the near wellbore areas adjacent to a hydrocarbon bearing formations and coal bed methane formations. In a particular aspect, the invention relates to removing liquids such as water and/or oil from the formation near the wellbore. The cleaning and liquid removal is accomplished with liquid carbon dioxide or a treatment medium that includes liquid carbon dioxide. The treatment medium is injected into the wellbore through tubing in a controlled manner so that the treatment medium enters the formation in a liquid state, although a portion may be allowed to vaporize upon introduction into the wellbore. The treatment medium is then allowed to vaporize and loosen and entrain undesirable materials from the formation and from within the wellbore or casing, and mobilize water and oil present by effervescing and by dissolving.

Abstract: Methods and compositions useful in inhibiting the formation, growth, and/or maintenance of gas hydrates in a fluid mixture. The gas hydrate inhibitors comprise polyetheramines and acids that are exothermically reacted in situ to produce polyetherammonium compounds.

Abstract: The invention relates to a process of cleaning boreholes, boring equipment and borings with an aqueous cleaning of one more lithium salts of alkyl sulfates of formula (I): R—O—SO3?Li+??(I) in which R is a saturated, unsaturated, branched or linear alkyl group containing 8 to 22 carbon atoms, preferably the lithium salts of alkyl sulfates are comprised of a mixture of those in which R is a saturated, linear alkyl groups having 8 to 14 carbon atoms.

Abstract: This invention relates to methods for reducing the viscosity of hydrocarbon liquids encountered in petroleum operations. The method includes forming a low viscosity emulsion by contacting hydrocarbon liquids with an effective amount of a water-soluble polymer having pendant methyl ether groups.

Abstract: The annular surface between the tubing and casing of an oil or gas well as well as flow conduits and vessels may be contacted with a foamed treatment composition containing a gas, a foaming agent and a treatment agent. The treatment agent may be an inhibitor or removal agent for scales, corrosion, salts, paraffins or asphaltenes. The foam, upon destabilization, renders a thin film of concentrated treatment agent on the external surfaces of the tubing, inside the casing and in the perforations of the oil or gas well or on the flow conduits or vessels.

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 method of treating a subterranean formation penetrated by a wellbore of a well having iron-containing components is carried out by introducing a treatment fluid into the wellbore of the well. The treatment fluid is formed from an aqueous solution, a mineral acid, a viscoelastic surfactant gelling agent and corrosion inhibitor system containing at least one of an alkyl, alkenyl, alicyclic or aromatic substituted aliphatic ketone and aliphatic or aromatic aldehyde. The treatment fluid is substantially free of any formic acid or precursor formic acid. In certain embodiments, the corrosion inhibitor system comprises a mixture of at least one of an alkenyl phenone or ?,?-unsaturated aldehyde, an unsaturated ketone or unsaturated aldehyde other than the alkenyl phenone and ?,?-unsaturated aldehyde, a dispersing agent, an extender and an alcohol solvent. A corrosion inhibitor intensifier may also be used in certain embodiments, which may include a mixture of cuprous iodide and cuprous chloride.

Abstract: A composition and method for breaking down and denaturing friction-reducing compound introduced into the ground during the drilling of gas and oil wells and for destroying other contaminants and biohazards naturally present within and artificially introduced into hydrocarbon wells, which are formed as a result of the drilling and pumping processes. The composition includes several species of oxidizing agent compounds that are effective in breaking down hydrogen sulfide produced by bacteria as well as the friction-reducing polymer used during drilling and several other organic compounds.

Abstract: A water based drilling fluid contains as additive one or more alkyl ethoxylates having the formula RO(CH2CH2O)nH; wherein: R is a C16-22alkyl group (preferably R is aliphatic and more preferably R is linear), and n is an integer in the range 2-30. The fluid further contains one or more viscosifying agents, and is substantially clay-free.

Abstract: A method of treating liquid, particularly an oil/water mixture, in an oil well pipe, wherein a radio frequency propagating electrical field is established in the liquid in the pipe cause the formation of seed crystals or scale-forming material in the liquid, on which seed crystals asphaltenes and/or paraffin waxes in the liquid are deposited so that they are carried through the pipe with the liquid in preference to being deposited on the pipe wall.

Abstract: A wellbore chemical treating system includes a pressure vessel for containing a treating chemical. The pressure vessel is closed to atmospheric pressure. A first controllably operated valve is disposed in fluid communication between an outlet of the pressure vessel and a well for selectively controlling the flow of the chemical from the pressure vessel to the well. A pressurized gas is disposed in the pressure vessel wherein the pressure exerted by the pressurized gas causes the chemical to flow from the pressure vessel to the well through the first valve when the first valve is opened. A second controllably operated valve is disposed in fluid communication between the well and an outlet of a fluid tank for selectively controlling flow of fluid in the tank to the well. The fluid tank is replenished by fluid produced from the well. The system includes a controller for selectively operating the first valve and the second valve.

Abstract: The permeability of a subterranean formation is improved by introducing into the formation a water-in-oil emulsion. Unwanted particulates deposited in the formation during the production of oil are dissolved or loosened by the outer phase of the emulsion and dispersed in the aqueous phase.

Abstract: Single phase microemulsions improve the removal of filter cakes formed during drilling with oil-based muds (OBMs). The single phase microemulsion removes oil and solids from the deposited filter cake. Optionally, an acid capable of solubilizing the filter cake bridging particles may also be used with the microemulsion. In one non-limiting embodiment the acid may be a polyamino carboxylic acid. Skin damage removal from internal and external filter cake deposition can be reduced. In another optional embodiment, the single phase microemulsion may contain a filtration control additive for delaying the filter cake removal, destruction or conversion.

Abstract: Oilfields are stimulated by injecting an inflow stream of a fluid into an oil producing well linked to the oilfield, displacing the oil and recovering an outflow stream of fluid comprising the oil, wherein at least two streams are injected into at least two production zones of an oil well or are injected into at least two different oil producing wells from which at least two outflow streams from the two zones or wells are combined before recovering, with a scale inhibitor having detectable moieties being introduced into the oilfield(s) and/or into the fluid, and wherein two different scale inhibitors are used, dedicated to the two zones or wells, said different scale inhibitors having different detectable moieties that can be distinguished by analysis.

Abstract: Methods comprising: providing a subterranean formation penetrated by a well bore wherein the well bore comprises perforated casing that comprises a plurality of perforations, providing an acidic treatment fluid comprising an aqueous base fluid and an acid composition, placing the acidic treatment fluid in the well bore in a manner that allows the acidic treatment fluid to reduce debris present in the perforations, providing a consolidating agent, and placing the consolidating agent in a near well bore region.

Abstract: A process for fracturing a subterraneous formation in the production of an oil well is described. The process steps include injecting an initial charge of a mixture, the mixture being formed from at least diatomaceous earth and at least one well treatment agent, into a well bore formed in the subterraneous formation so as to form a down-hole matrix within the formation; injecting a solution comprised of an additional amount of the well treatment agent into the formation after the initial charge of the at least one well treatment agent has been substantially depleted; and then pressurizing the well bore for a time and under conditions sufficient to reactivate the down-hole matrix in the formation, so that the treatment agent activity of the matrix is increased relative to the treatment agent activity of the matrix just prior to injecting the solution.

Abstract: A method of reducing wax deposition in an oil wellbore tubing includes providing an aqueous bioslurry comprising at least one microbe capable of degrading paraffin wax at about 20-45° C. and a nutrient medium containing one or more carbon source and an oxygen slow-releasing compound. The method further includes providing an oil wellbore completion having a production tubing with an interior surface including a zone that is susceptible to wax deposition when the well is operated to produce oil. The method further includes, while oil production from the well is stopped, incubating the biological slurry in the wax-deposition zone tubing for a sufficient time to multiply the microbe(s) and form a biofilm on at least the wax-susceptible zone.

Abstract: Methods and compositions for hindering asphaltene deposition. One method comprising: identifying an interval of the subterranean formation to be treated with a relative permeability modifier to hinder subsequent asphaltene deposition; introducing the relative permeability modifier into the subterranean formation; and allowing the relative permeability modifier to contact the interval, thereby attaching to surfaces within the subterranean formation and hindering subsequent asphaltene deposition.

Abstract: A method to enhance oil recovery from a subterranean reservoir, the reservoir being accessible via a production well. The method includes injecting a surfactant solution that includes surfactants into the production well. The surfactant solution selected to increase an oil-to-water ratio of oil recovery from a porous matrix portion of the reservoir. The method also includes injecting a well-servicing volumetric solution into the production well to perform a second well treatment process. The second well treatment process is selected from the group consisting of a scale inhibition squeeze process, a well acidizing process, a chemical process to reduce water production rate, an acid fracturing process, and a hydraulic fracturing process. In the method, the surfactant solution and the second well treatment solution are injected into the production well within less than about six months of one another.

Abstract: A hydrocarbon extraction process enabling an acceleration in the production of the productive zone of the oil deposit of a well and an increase in the cumulated quantity of hydrocarbons, characterized by the fact that a hot fluid constituted of hydrocarbons is made to circulate so as to bring the productive zone locally to a higher temperature by conduction in order to fluidify the hydrocarbons imprisoned in an underground reservoir, by means of a thermally-insulated pipe, the hot fluid being mixed with the hydrocarbons extracted via a liner or drain in the productive zone such mixture thus formed being recovered at the surface by means of an pumping pipe.

Abstract: Disclosed are methods for solution mining of evaporite minerals, such as trona, comprising drilling an access well and at least two lateral boreholes; injecting a fluid; circulating the fluid through the lateral boreholes with a controlled fluid flow; and collecting a pregnant solution. Also disclosed are methods of solution mining that include injecting an aqueous solution into an underground trona cavity at a temperature sufficient to maintain at least a portion of the solution in the cavity in the Wegscheiderite solid phase region; removing aqueous solution from the cavity; and recovering alkaline values from the removed aqueous solution. Also disclosed are methods of solution mining that include injecting an aqueous solution into an underground trona cavity; removing aqueous solution from the cavity, wherein the temperature of the removed aqueous solution is at about the TWA point temperature; and recovering alkaline values from the removed aqueous solution.

Abstract: An aqueous fluid useful for the recovery of crude oil from a subterranean formation, including water and one or more organophosphorus materials and methods for using same.

Abstract: Composites containing a hydrocarbon-soluble well treatment agent may be supplied to a well using a porous particulate. Such well treatment agents may for example inhibit the formation of paraffins, salts, gas hydrates, asphaltenes and/or other deleterious processes such as emulsification (both water-in-oil and oil-in-water). Further, other well treatment agents include foaming agents, oxygen scavengers, biocides and surfactants as well as other agents wherein slow release into the production well is desired.

Abstract: Gas hydrates, particularly natural gas hydrates e.g. methane hydrates, may be formed and controlled within conduits and vessels by imparting energy to gas and water, for instance using agitation or vibration. The systems and methods allow for improved flow characteristics for fluids containing the gases, e.g. hydrocarbon fluids being transported, and for improved overall efficiencies. The gas and water within a gas flow path may be perturbed or agitated to initiate formation of relatively small hydrate particles. The hydrate particles continue to form as long as energy is imparted and water and hydrate guest molecules are available. High amplitude agitation of the gas and water will repeatedly break up agglomerated hydrate particles that form and encourage the formation of more and smaller particles. As more hydrate forms in this manner, less and less free water may be available proximate the gas and water contact.

Abstract: Disclosed are paraffin inhibitors prepared by admixing a polymer having the characteristic of inhibiting paraffin crystalline growth in formation fluid from oil and gas wells with a first solvent selected from the weak to moderate wax solvents and a second solvent selected from the strong wax solvents. Exemplary weak to moderate wax solvents include benzene, toluene, xylene, ethyl benzene, propyl benzene, trimethyl benzene and mixtures thereof. Exemplary strong wax solvents include cyclopentane, cyclohexane, carbon disulfide, decalin and mixtures thereof. The solvent system disclosed has desirably better solubility with the polymers, even at reduced temperatures, than either solvent alone. It is emphasized that this abstract is provided to comply with the rules requiring an abstract which will allow a searcher or other reader to quickly ascertain the subject matter of the technical disclosure. It is submitted with the understanding that it will be used to interpret or limit the scope or meaning of the claims.

Abstract: Installation for enhanced oil recovery comprising in succession: a polymer storage hopper, a grinding device, a dissolution/maturation tank for the dispersed polymer, and a pump for transferring pressurized polymer solution in the pipeline conveying the injection water for introducing the mixture of polymer and injection water into a well. The grinding device has a chamber for grinding and draining the dispersed polymer comprising a rotor and a stator, and on all or part of the periphery of the chamber, a ring fed by a secondary water circuit. The ring communicates with the chamber for spraying of pressurised water on the blades of the stator. A method implementing the installation is also provided.

Abstract: A fluid conditioning system designed to be installed between the well perforation and the intake of a pump used to effect artificial lift is used to filter and chemically treat production fluids. The fluid conditioning system is an apparatus that provides scale inhibitors and/or other chemical treatments into the production stream. In some embodiments, the fluid conditioning system may be a part of the production stream filter wherein the filtering material is comprised of a porous medium that contains and supports the treatment chemical. In other embodiments, the chemical treatment may be accomplished by the gradual dissolution of a solid phase chemical. The treating chemical may be recharged or replenished by various downhole reservoirs or feeding means. In yet other embodiments, the treating chemical may be replenished from the surface by means of a capillary tube.

Abstract: Asphaltene control additives are added to base fluids which are introduced directly or indirectly into a hydrocarbon-bearing formation to mitigate asphaltene deposition in the formation which results in improved permeability in the formation and production of hydrocarbons therefrom. The fluids to which the additive is added may be liquid CO2-based, aqueous-based or non-aqueous-based fluids. Further, the fluids are fracturing fluids, drilling fluids and wellbore treatment fluids such as acidizing fluids.

Abstract: A method for cleaning oil wells to increase the flow of oil thereof by use of a unique aqueous cleaning emulsion comprising of water, hydrocarbon solvent, and detergent. This one step method provides for the simultaneously cleaning/removal of asphaltene and/or paraffin and scale. This method can be used alone or with the assistance of a wash tool which is a combination pressure and surge wash tool having a nipple assembly. A by-pass port is coupled to the nipple assembly and a diverter cup is coupled to the by-pass port. A plurality of pressure wash cups are positioned on the tool. A pressure wash port is located between the plurality of pressure wash cups and a pump shoe assembly is coupled to a bottom pressure wash cup.

Abstract: Disclosed is a system for injecting an enzymatic fluid composition into a gas or gas and oil near-well bore having a wide temperature range. The enzymatic fluid composition is a treatment for reducing oil deposits, asphaltenes, waxes, scale, or other hydrocarbon materials in a gas well or a combination gas/oil well where the production of gas is greater than 50% on a barrel of oil equivalent (BOE) basis.

Abstract: A composite of a well treatment agent adsorbed onto a water-insoluble adsorbent is useful in the treatment of oil and gas wells and may be introduced, as a well treatment fluid, with a carrier fluid. The water-insoluble adsorbent may be activated carbon, silica particulate, precipitated silica, zeolite, diatomaceous earth, ground walnut shells, fuller's earth and organic synthetic high molecular weight water-insoluble adsorbents. Suitable as the well treatment agent are scale inhibitors, corrosion inhibitors, paraffin inhibitors, salt inhibitors, gas hydrate inhibitors, asphaltene inhibitors, oxygen scavengers, biocides, foaming agent, emulsion breakers and surfactants.

Abstract: Fluid producing or injecting wells may be treated with a water-in-oil emulsion for the removal or inhibition of unwanted particulates, including pipe dope, asphaltenes and paraffins. In addition, such emulsions are effective in the displacement of oil base drilling muds and/or residues from such muds from wells. The emulsion may also be used to break the interfacial and/or rheological properties of oil base mud and synthetic oil base mud filter cakes, and act as a demulsifier to break the water-in-oil emulsion present in such oil base and synthetic oil base muds. The water-in-oil emulsions may optionally contain a dispersing agent as well as a surfactant.

Abstract: Hydraulic fracturing of wells by injecting a degradable polymer phase as a fracturing fluid is provided. Composition and degree of polymerization of the degradable polymer and the selection of additives may be varied to adjust the viscosity, degradation time and other properties of the fracturing fluid. Viscous degradable fluid or pellets of degradable polymer may be placed in a wellbore as an internal phase in a low viscosity carrier fluid. A polymer-continuous liquid phase may be formed at a selected location in the wellbore, usually near perforations, before the polymer phase is pressured into a formation to form a hydraulic fracture.

Abstract: The annular surface between the tubing and casing of an oil or gas well may be contacted with a foamed well treatment composition containing a gas, a foaming agent and a liquid well treatment agent, such as a scale inhibitor, corrosion inhibitor, salt inhibitor, scale remover or biocide. The foam, upon destabilization, renders a thin film of concentrated well treatment agent on the external surfaces of the tubing, inside the casing and in the perforations.

Abstract: A process for inhibiting souring in a hydrocarbon reservoir provides a feed water including a plurality of phosphorous constituents and having an elevated phosphorous concentration. At least some of the phosphorous constituents are removed from the feed water to produce a treated injection water, which has a reduced phosphorous concentration less than the elevated phosphorous concentration. The treated injection water is injected into the reservoir via a first well and the hydrocarbon is produced from the reservoir via a second well. The process inhibits souring in the reservoir insofar as the treated injection water results in a lower level of souring in the reservoir over time than if the feed water had been injected into the reservoir.

Abstract: One or more valves can be run into a string to land near associated ports in the string for injection or/and production service. When multiple valves are installed they can be initially configured to balance flow into or from a zone. The position of each valve can be altered without removal from the string preferably by a wireline shifting tool. One or more valves can also be removed and replaced when worn preferably using a wireline run tool. The valves can come with an integral sand control feature to facilitate production. Sensors to monitor well conditions and to transmit data to the surface can also be incorporated into the valve module.

Abstract: Fluid producing wells may be treated with a water-in-oil emulsion for the removal or inhibition of unwanted solid particulates, including pipe dope, asphaltenes and paraffins. Such emulsions are of particular applicability in the displacement of oil base drilling muds and/or residues from such muds from producing wells. The water-in-oil emulsions may optionally contain a dispersing agent as well as a surfactant.

Abstract: Method and apparatus for melting a material and squeezing the melted material through casing perforations into a fault within the cement or formation of an oil or gas well. A heating tool carries solid material which is melted at depth within the well and adjacent to the casing perforations. The liquefied material is forced through the perforations and into the formation or the well cement. When the material cools and solidifies, the faults become sealed.

Abstract: An improved acidization method is provided in which an aqueous solution comprising one or more esters or polyesters of lactic acid or of glycerol is placed in a well where the esters or polyesters undergo hydrolysis. The hydrolysis of the esters or polyesters occurs at a slower reaction rate than that of several other known acidization esters, such as diethyleneglycol diformate, at temperatures higher than 60° C. or even higher than 100° C. Thus, the solution may be distributed substantially throughout a region in the well where acidization is required before hydrolysis is completed, despite being exposed to relatively high temperatures.

Abstract: A method of delivering chemicals such as scale inhibitor into a wellbore producing fluids includes providing the chemicals, in a slow-release form, in a container located in the path of the production fluids so that the production fluids pass through the container. Preferably, the container is suspended in the production tubing and periodically retrieved from the well to be refilled.

Abstract: An apparatus and method for controlling and/or minimizing the formation or accumulation of unwanted deposits on the inside of fluid flow paths by employing at various locations along the path an assembly of permanent magnets oriented such that the fluid flow is preferably from the North magnetic pole to the South magnetic pole.

Abstract: Methods and compositions for use in subterranean operations, and more particularly, additives comprising one or more silicates used to treat tar resident in a well bore, and methods of use, are provided. In one embodiment, the method comprises a method of treating tar resident in a well bore comprising providing a tar-treating additive comprising one or more silicates introducing the tar-treating additive into the well bore; and allowing the tar-treating additive to react with the tar resident in the well bore so as to at least partially reduce the adhesiveness of the tar.

Abstract: A biodegradable water-in-synthetic oil base emulsion, effective in the removal of filter cakes, consists of an external phase of a surfactant emulsified in a paraffinic base oil. The emulsion is particularly effective in breaking-down the interfacial rheological properties of oil base mud and synthetic oil base mud filter cakes and acts as a demulsifier to break the water-in-oil emulsions present in such oil base and synthetic oil base muds.

Abstract: A method of treating a well consists of introducing into the wellbore a biodegradable fluid system containing a fatty acid ester, such as methyl soyate. The fluid system may further contain a lactic acid ester, such as ethyl lactate, and/or a nonionic surfactant. The fluid system may be used in displacement, well remediation and stimulation as well as additional, alternative applications such as the cleaning of surface and/or downhole equipment.