Abstract: A new hydrocarbon fluid composition and methods of using the fluid are disclosed. The fluid is comprised of a liquid hydrocarbon, a phosphate ester, an iron or aluminum salt crosslinker, a hydrocarbon foaming agent and a gas. The fluid can be used in many applications.

Abstract: Subject matter of the present invention is a drilling fluid additive based on sulfonated asphalt, which comprises a water soluble and anionic polymer component in quantities of 0.1 to 20 wt. %, with respect to the total additive in addition to the asphalt component. With this additive the water solubility of sulfonated asphalt can be markedly increased. This additive, whose polymer component is thermally highly stable, is utilized primarily in water- and/or oil-based drilling fluids and in particular in the exploration of subterraneous petroleum and natural gas deposits. Typical polymer components to consider are representatives of polycondensation products, such as phenol resins, ketone resins and sulfonated naphthalene, acetone and amino plasticizer resins (for example urea and melamine resins).

Abstract: Metal cross-linked phosphate ester compositions impart fragile progressive gel structure to a variety of oil and invert emulsion-based drilling fluids at neutral or acidic pH. The fluids are useful for drilling wellbores in subterranean formations without need for organophilic clays to suspend drill solids. At greater concentrations, metal cross-linked phosphate ester compositions enhance fluid viscosity for suspending weighting materials in drilling fluids during transport of the fluids, as from a manufacturing or mixing facility to a drilling site.

Abstract: Improved in-situ filter cake degradation compositions for use in subterranean formations, well drill-in and servicing fluids including such in-situ filter cake degradation compositions, and methods of using such in-situ filter cake degradation compositions and well drill-in and servicing fluids in subterranean operations are provided. An example of a method is a method for forming a self-degrading filter cake in a subterranean formation. Another example of a method is a method of drilling a well bore in a subterranean formation. Another example of a method is a method of degrading a filter cake in a subterranean formation. An example of a composition is a well drill-in and servicing fluid. Another example of a composition is an in-situ filter cake degradation composition.

Abstract: The present invention relates to emulsion compositions and associated methods. More particularly, the present invention relates to gelled invert emulsion compositions and their associated methods of use and preparation. In one embodiment, the present invention provides a method of treating a portion of a subterranean formation comprising the steps of: providing a gelled invert emulsion composition that comprises an oleaginous continuous phase, a discontinuous phase, and a gelling agent; and treating a portion of the subterranean formation. The present invention also provides methods of increasing the viscosity of an invert emulsion composition, methods of making gelled invert emulsion compositions, methods of providing some degree of sand control to portions of subterranean formations, methods of fracturing a portion of a subterranean formation, and gelled invert emulsion compositions.

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: The present application relates to granules of powdery mineral particles produced by spray granulation of a liquid slurry comprising powdery minerals particles having particle size below 10 m, at least one water-reducing agent and/or at least one binder agent and/or at least one dispersing agent. The application further relates to a method for producing such granules.

Abstract: A downhole servicing composition comprising from about 15 percent to about 80 percent by weight of a clay, and from about 10 percent to about 75 percent by weight of a carbon source is disclosed. The invention includes a downhole servicing composition comprising from about 15 percent to about 45 percent by weight of a first clay, from about 15 percent to about 45 percent by weight of a second clay, from about 10 percent to about 35 percent by weight of a filler, and from about 10 percent to about 75 percent by weight of a carbon source. The invention also includes a downhole servicing composition comprising an aqueous base and from about 10 percent to about 75 percent by weight of flaked graphite, wherein the downhole servicing composition has a thermal conductivity not less than about 0.8 BTU/hr-ft-° F.

Abstract: A method of controlling the pressure of a casing annulus in a subterranean well that includes injecting into the casing annulus a composition including a base fluid and a polymer coated colloidal solid material. The polymer coated colloidal solid material includes: a solid particle having an weight average particle diameter (d50) of less than two microns, and a polymeric dispersing agent coated onto the surface of the solid particle during the comminution (i.e. grinding) process utilized to make the colloidal particles. The polymeric dispersing agent may be a water soluble polymer having a molecular weight of at least 2000 Daltons. The solid particulate material may be selected from materials having of specific gravity of at least 2.68 and preferably the solid particulate material may be selected from barium sulfate (barite), calcium carbonate, dolomite, ilmenite, hematite, olivine, siderite, strontium sulfate, combinations and mixtures of these-and other similar solids.

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 comprising at least one polymerizable monomer and at least one antistatic agent to control build up of static charge. The second fluid 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 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: 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: Pumpable multiple phase vesicle compositions carry agents and components downhole or through a conduit, and controllably releasing them at a different place and time by breaking the compositions. In one non-limiting embodiment the pumpable multiple phase vesicles have a third phase containing a first phase which bears the agent to be controllably released. The first and third phases of the vesicles are separated by a surface active material bilayer that forms the second phase. The pumpable multiple phase vesicles may have internal and external phases that are both oil miscible, both aqueous miscible, or both alcohol miscible. The surface active material bilayer may be composed of compounds such as phospholipids, alkyl polyglycosides, gemini surfactants, sorbitan monooleate, sorbitan trioleate, and many others. The agent may be released by one or more of a variety of mechanisms.

Abstract: Improved methods and compositions for treating subterranean formations penetrated by well bores are provided. A method for breaking a gelled hydrocarbon fluid comprised of a hydrocarbon liquid, a ferric iron or aluminum polyvalent metal salt of a phosphonic acid ester or dialkylphosphinic acid is provided.

Abstract: Provided herein are defoaming agents that comprise lecithin and a solvent. Optionally, they may comprise hydrophobic particles. One embodiment provides a method comprising: providing a well fluid that comprises foam; providing a defoaming agent that comprises lecithin and a solvent; and contacting the well fluid with the defoaming agent so that the amount of foam present in the well fluid is reduced.

Abstract: A method for using an invert emulsion fluid in a well bore, comprising placing an invert emulsion fluid in a well bore, wherein the invert emulsion fluid comprises an oleaginous fluid, a non-oleaginous fluid and an emulsifier comprising one or more amines generally represented by the formula: wherein R is a radical selected from the group consisting of abietyl, hydroabietyl, dihydroabietyl, tetrahydroabietyl, and dehydroabietyl, each R? may be the same or different and is an alkyl having from about 1 to about 3 carbons, each A may be the same or different and is NH or O, and the sum of x and y ranges from about 1 to about 20, and contacting the invert emulsion fluid with an acid solution to reversibly convert the invert emulsion to an oil-in-water emulsion.

Abstract: A process to substantially reduce fluid loss in which an appropriate amount of a non-flowing gel of sufficient strength is emplaced to substantially eliminate or reduce loss of the drilling fluid. The gel composition of the process includes: (1) a non-cellulose containing copolymer having vinyl phosphonate co-monomer units which may be incorporated into the polymer by copolymerization with the other co-monomer(s) comprising the polymer or by grafting upon an already existing polymer or co-polymer, (2) a crosslinking agent active upon the phosphonate groups, (3) a crosslinking initiator comprising a Bronsted Lowry base or Lewis base and (4) an aqueous solvent.

Abstract: A method of improving the lubricity of an aqueous based drilling fluid composed of an aqueous base fluid, and a weighting agent. The method involves the addition of an effective amount of a phospholipid to substantially reduce the coefficient of friction when compared to the fluid absent the phospholipids. Preferably the phospholipids have the structure: in which R and R? are C6 to C25 hydrocarbon groups; and A is an anion to counter the cationic charge.

Abstract: Fluids useful in oil well drilling operations are described. The fluids comprise standard viscosifying and fluid loss control additives along with phosphonates or phosphate esters of organic ligands. The addition of the phosphonates or phosphate esters at effective concentrations prevents the adherence of heavy oil and heavy oil laden drill cuttings to drill pipe strings and well bore casings.

Abstract: Grout slurries are provided that have high thermal conductivities of greater than about 1.4 Btu/hr-ft-° F. and low hydraulic conductivities ranging from about 5×10?9 cm/s to about 1×10?8 cm/s. Such grout slurries comprise water and a grout composition that is available as a one-sack product. The grout composition includes calcium bentonite present in an amount of from about 15% to about 45%, sodium bentonite present in an amount of from about 15% to about 45%, silica flour present in an amount of from about 10% to about 35%, and flaked graphite present in an amount of from about 10% to about 75%, all by weight of the grout composition. Further, methods of installing a conduit such as a heat transfer loop in a hole in the earth include placing the conduit in the hole, forming the foregoing grout slurry, and placing the grout slurry in the hole adjacent to the conduit.

Abstract: Invert emulsion drilling system fluids comprising an oleaginous continuous phase and a non-oleaginous dispersed phase, the dispersed phase comprising organofunctional compound(s) effective to provide shale inhibition. The organofunctional compound(s) may be used either as a supplement to or as a substitute for metallic salts.

Abstract: A well drilling method comprises removing the drilling cuttings using an aqueous drilling fluid such as a foam including a foaming agent which includes at least one mono-(aliphatic hydrocarbyl) phosphate ester. More specifically, the drilling fluid takes the form of a potassium and/or alkanolamine and/or alkylalkanolamine salt, the foam also comprising a foam stabiliser.

Abstract: An invert emulsion fluid, method for making same, and method for using same as a servicing fluid in a well bore. The invert emulsion fluid contains an oleaginous fluid, a non-oleaginous fluid, and an emulsifier comprising one or more amines generally represented by the formula: wherein R is a cycloaliphatic hydrocarbon, each R? may be the same or different and is H or an alkyl having from about 1 to about 3 carbon atoms, each A may be the same or different and is NH or O, and the sum of x and y ranges from about 1 to about 20. In a preferred embodiment, R is a radical selected from the group consisting of abietyl, dihydroabietyl, tetrahydroabietyl, and dehydroabietyl, R? is H, and A is O.

Abstract: Clay is stabilized in the drilling of wells and other formation treatment for hydrocarbon production by the addition to the drilling or other fluid fluid of potassium formate together with a cationic formation control additive.

Abstract: A method and composition is provided for sealing a subterranean zone penetrated by a well bore to restore lost circulation. In one embodiment, the composition comprises a pellet comprising a mixture of lost circulation materials (LCMs).

Abstract: Additives for drilling fluids, in particular for water-based drilling fluids are described which when added to the fluid at levels of up to 10% weight by volume reduces the accretion and bit-balling tendencies of shale cuttings exposed to said fluids. The additives are based on phosphonate chemistry, and are of the general class (I), wherein R, R′ and R″ are radicals exclusively containing H atoms or combinations of H, C, O or P atoms up to a maximum of 100 atoms.

Abstract: A wellbore fluid having a non-aqueous continuous liquid phase that exhibits an electrical conductivity increased by a factor in order of 104 to 107 compared to conventional invert emulsion comprises from about 0.2% to about 10% by volume of carbon black particles and one or more emulsifying surfactant(s) selected from the class including nonionic emulsifiers of Hydrophilic-Lipophilic Balance (HLB) less than about 12, and anionic surfactants wherein the counter-ion (cation) is any of alkali metal, ammonium, or hydrogen ions. This wellbore fluid can be used for drilling or completing a well and can be used for providing enhanced information from electrical logging tools, measurement while drilling, logging while drilling, geosteering and the like.

Abstract: An additive which increases the density of wellbore fluids used during the construction or repair of oil, gas, injection, water or geothermal wells comprises solid colloidal particles of weight average particle diameter (D50) of less than 2 microns, the particles being deflocculated by the action of a dispersant, preferably incorporated during the process of grinding or communication of the particles to the specified particle size. The additives may be used in any wellbore fluid such as drilling, cementing, completion, packing, work-over (repairing), stimulation, well killing and spacer fluids as well as in a dense media separating fluid or in a ship's ballast fluid.

Abstract: This invention relates to a well treatment fluid and a method to treat an/or fracture a subterranean formation comprising: injecting a well treatment fluid into the formation at sufficient pressure to fracture the formation wherein the fluid comprises: (a) one or more amphoteric surfactants; (b) water; (c) one or more nonaqueous solvents; (d) optionally, an acid forming compound; and (e) provided that if the acid forming compound is present a hydrophilic alcohol may also be optionally present; wherein the all or part of the fluid forms vesicles.

Abstract: A method of inhibiting or retarding formation of hydrates from water and a lower alkane, such as methane or ethane, involves adding additives which comprise (i) a corrosion inhibitor and (ii) a salt which is of formula [R1(R2)XR3]+Y−, wherein each of R1, R2 and R3 is bonded directly to X, each of R1 and R2, which may be the same or different is an alkyl group of at least 4 carbons, X is S, NR4 or PR4, wherein each of R3 and R4 which may be the same or different represents hydrogen or an organic group, with the proviso that at least one of R3 and R4 is an organic group of at least 4 carbons, and Y is an anion, the additives being added in an amount effective to inhibit or retard hydrate formation, to a medium susceptible to hydrate formation.

Abstract: A biodegradable drilling mud, comprising a water/organic phase reverse emulsion in a volume ratio ranging from 50/50 to 10/90, which contains: a) from 1 to 5% by volume of at least one nitrogen compound selected from the group consisting of amino acids, carbamic mono- and polyamides and mono- and polycarbamic amides, of formulae (I) and (II) respectively, taken alone or as a mixture: R—[NH—CH2]n—CO—NH2  (I) R—NH—[CO—NH]m—H  (II)  wherein R is hydrogen or an alkyl group comprising from 1 to 10 carbon atoms and n and m are integers ranging from 1 to 5, b) from 2 to 10% by volume of at least one phosphorus derivative selected from the group consisting of surfactant phosphorus compounds, and c) from 2 to 10% by volume of at least one oxygenated compound selected from the group consisting of fatty acids, fatty acid esters of fatty alcohols comprising carbon-based chains comprising from 12 to 24 carbon atoms, alone or

Abstract: The invention relates to the use of (A) esters of phosphoric acid and/or partial salts thereof with alkoxylated aliphatic, cycloaliphatic and/or aromatic alcohols and/or (B) fatty acid oligo-dialkanolamides as inhibitors against the formation of incrustations based on organic solids from liquid and/or gaseous hydrocarbon mixtures which are fluid and prone to form such incrustations. Preferred inhibitors having a surface-active character are capable of wetting, and especially of spreading on, solid work material surfaces also in the presence of the fluid hydrocarbon phase. They are particularly suitable as additives to crude oils and/or oil fractions susceptible of forming incrustations.

Abstract: The invention relates to multiphase lubricant concentrates with improved properties for use in aqueous fluids for geological exploration by drilling which contain organic lubricating components which are solid and/or liquid at room temperature (O phase) together with emulsifiers finely dispersed in a continuous aqueous phase (W phase). These concentrates are characterized in that the system of O phase/W phase and emulsifiers has a phase inversion temperature (PIT) above room temperature and has been produced by heating the multiphase system to temperatures equal to or above the PIT and subsequent cooling to temperatures below the PIT. The present invention also relates to the use of the multiphase lubricant concentrates as an additive in water-based fluids for use in geological exploration by drilling and for the subsequent treatment of the resulting boreholes.

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 phosphate and 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 phosphate is preferably a phosphate ester, ether phosphate, or soluble phosphate having a molecular weight in the range of about 300 to bout 900. The phosphate is able to operate at temperatures prevailing in drilling mud systems. 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.

Abstract: The present invention relates to an oil-based drilling fluid, a continuous phase for an oil-based drilling fluid, and additives for an oil-based drilling fluid. The drilling fluid, the continuous phase of the drilling fluid, and the additives for the oil-based drilling fluid are characterized by non-fluorescence (defined as a fluorescence intensity of 800 or less) when exposed to ultraviolet light. The continuous phase of the drilling fluid is composed of synthetic hydrocarbons selected from the group consisting of oligomers synthesized from one or more alphaolefins containing a C.sub.2 to C.sub.14 chain length, wherein the oligomers have an average molecular weight of from 120 to 100, and additives. The additives of the continuous phase include surfactants, wetting agents and/or emulsifiers.

Abstract: Corrosion of iron-containing metal surfaces in a hydrocarbon fluid having a temperature of from about 175.degree. C. to about 400.degree. C. and containing a corrosive amount of naphthenic acid is inhibited by adding to the fluid or to a feed therefor, in a total additive amount sufficient to effect corrosion inhibition in said fluid, one or more thiophosphorus compound, a salt thereof, an alkyl or aryl ester thereof, an isomer thereof, or some combination of the foregoing, thereby to effect inhibition of naphthenic acid induced corrosion in the fluid.

Abstract: The invention relates to a gel made of apolar medium including:an apolar medium,a "multichain" liquid surface-active agent in acidic form, soluble or dispersible in the said apolar medium,an agent for neutralizing the said "multichain" surface-active agent,from 0.2 to 5 molecules of water per molecule of "multichain" surface-active agent,optionally at least one emulsifying agent and/or a solid filler which is soluble or insoluble in the apolar medium.This gel may be employed for the formulation of water-based drilling fluids.

Abstract: An oil-in-water emulsion composition is disclosed which comprises a mixture of water and(A) at least one oil comprising(1) a natural oil or synthetic triglyceride of the formula ##STR1## wherein R.sup.1, R.sup.2 and R.sup.3 are independently saturated or unsaturated aliphatic groups that contain from about 7 to about 23 carbon atoms;(2) a synthetic ester base oil comprising the reaction of a monocarboxylic acid or a dicarboxylic acid or an aryl carboxylic acid;(3) an olefin;(4) a polyolefin;(B) at least one phosphite ester of the formula ##STR2## wherein R.sup.11 and R.sup.12 are independently aliphatic, aryl or aliphatic substituted aryl groups that independently contain from 6 to 30 carbon atoms; and(C) at least one emulsifier.

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 phosphate and 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 phosphate is preferably a phosphate ester, ether phosphate, or soluble phosphate having a molecular weight in the range of about 300 to bout 900. The phosphate is able to operate at temperatures prevailing in drilling mud systems. 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.

Abstract: The invention relates to clay stabilizing agents for use in an alkaline water-base fluid such as a drilling mud and the use of such clay stabilizing agents in the drilling of wells. The clay stabilizing agent comprises a polyfunctional polyamine reaction product prepared by the reaction of a polyamine base reactant with urea or a dialkylcarbonate or by reaction with urea and a dialkylcarbonate. The stabilizing agent is subject to subsequent acidification to reduce the pH thereof to a value of about 7 or less. The polyamine base reactant is selected from the group consisting of an aliphatic polyamine, a polyaliphatic polyamine, a heterocyclic polyamine, an alkylalkanol polyamine and mixtures thereof. Specifically, the base reactant comprises an aliphatic polyamine selected from the group consisting of ethylenediamine, diethylenetriamine, tetraethylenetetramine, and tetraethylenepentamine and mixtures thereof.

Abstract: An aqueous-based composition comprising a glycerophosphoric acid ester and a diacetyltartaric acid ester of mono and/or diglycerides when combined with viscosifier, sealant and weighting agent is suitable for use as a spotting fluid for downhole drilling operations for releasing stuck drill string. The present invention also enhances drill fluid lubricity, is nontoxic to marine life, non-polluting and may be safely disposed of in off-shore waters.

Abstract: The present invention relates to an improved continuous phase for an oil based drilling fluid and specifically a synthetic hydrocarbon continuous phase which is non-polluting and minimally toxic. The invention provides excellent drilling fluid properties under a wide variety of drilling conditions. The synthetic hydrocarbons are selected from the group consisting of branched chain oligomers synthesized from one or more olefins containing a C.sub.2 to C.sub.14 chain length and wherein the oligomers have an average molecular weight of from 120 to 1000. In the drilling fluid compositions, suitable emulsifiers, wetting agents, viscosifiers, weight materials and fluid loss additives are utilized in conjunction with water and/or a brine phase for the desired rheological properties.

Abstract: While many materials have been used to inhibit scale formation previously, none have been fully satisfactory to prevent scale formation and precipitation of totally dissolved solids (TDS) in fluids used in well drilling, completion and workovers when the fluids contain divalent metal cations and when the formation contains carbon dioxide. Since many wells are completed into such formations, a continuing search has been directed to an improved method for preventing the formation of such scale. According to the present invention, metal carbonate scale formation and TDS precipitation in a well penetrating a subterranean formation wherein a fluid containing calcium, magnesium, barium or zinc is used in the presence of carbon dioxide is prevented by maintaining the fluid at a pH from about 2 to about 9 and adding from about 1 to about 5000 parts per million of a phosphonomethylated oxyalkyleneamine material having a molecular weight from about 150 to about 3000 to the fluid.

Abstract: Novel compositions useful as fluid gelling agents, especially for use in subterranean applications such as drilling fluids, are prepared by reacting an aqueous dispersion of a clay, such as bentonite, with an aqueous gel of a monodispersed mixed metal layered hydroxide of the formula Li.sub.m D.sub.d T(OH).sub.(m+2d+3+na) A.sub.J.sup.n where D is a divalent metal, such as Mg, T is a trivalent metal, such as Al, and A represents other monovalent or polyvalent anions, the formula being described in detail in the disclosure.

Abstract: A drilling fluid includes water, bentonite, a weighting agent, and an additive comprising a water-soluble polycondensate containing phosphorous and nitrogen such as phosphorylated-urea-formaldehyde or phosphorylated-melamine-formaldehyde. Such additives provide the desired rheological and filtration loss properties as well as thermal and shear stability. The additives are prepared by reacting phosphorous acid, urea and formaldehyde according to a Mannich-type reaction.