Abstract: Environmentally acceptable or regulatory compliant oil-based drilling fluids and methods of using same in drilling a wellbore in a subterranean formation are disclosed. The fluids are able to meet environmental regulations while maintaining acceptable oil mud rheology and overall oil mud performance. The fluids are comprised of an invert emulsion. The base or continuous phase of the emulsion is comprised of esters blended with isomerized olefins, and/or other hydrocarbons, such as paraffins, mineral oils or glyceride triesters or combinations thereof. Alternatively, the emulsion has as a base comprising isomerized olefins blended with other hydrocarbons such as linear alpha olefins, paraffins or naphthenes.

Abstract: Methods for drilling, running casing in, and/or cementing a borehole in a subterranean formation without significant loss of drilling fluid are disclosed, as well as compositions for use in such methods. The methods employ drilling fluids comprising fragile gels or having fragile gel behavior and providing superior oil mud rheology and overall performance. The fluids are especially advantageous for use in offshore wells because the fluids exhibit minimal differences between downhole equivalent circulating densities and surface densities notwithstanding differences in drilling or penetration rates. When an ester and isomerized olefin blend is used for the base of the fluids, the fluids make environmentally acceptable and regulatory compliant invert emulsion drilling fluids.

Abstract: Methods for drilling, running casing in, and/or cementing a borehole in a subterranean formation without significant loss of drilling fluid are disclosed, as well as compositions for use in such methods. The methods employ drilling fluids comprising fragile gels or having fragile gel behavior and providing superior oil mud rheology and overall performance. The fluids are especially advantageous for use in offshore wells because the fluids exhibit minimal differences between downhole equivalent circulating densities and surface densities notwithstanding differences in drilling or penetration rates. When an ester and isomerized olefin blend is used for the base of the fluids, the fluids make environmentally acceptable and regulatory compliant invert emulsion drilling fluids.

Abstract: An inhibitive water-based polymer mud system and method for using the system in drilling and in stabilizing wellbores is disclosed for use in water sensitive formations as an alternative to oil-based muds. The system comprises a non-ionic low molecular weight polyacrylamide in combination with a non-ionic high molecular weight polyacrylamide, preferably long chain alcohol and poly anionic cellulose.

Abstract: A method of reducing the viscosity of oil-based drilling fluids and well service fluids at low temperatures and a thinner compound for use in such drilling fluids and well service fluids is disclosed. The method comprises adding to said drilling fluids or well service fluids a thinner having the formula: R—(C2H4O)n(C3H6O)m(C4H8O)k-H where R is a saturated or unsaturated, linear or branched alkyl radical having about 8 to about 24 carbon atoms, n is a number ranging from about 1 to about 10, m is a number ranging form about 0 to about 10, and k is a number ranging from about 0 to about 10.

Abstract: A superior powder form of a metallic soap for enhancing the properties of an invert emulsion drilling fluid may be prepared by a dry process saponification reaction. The process includes mixing a source of metal cations with the product of a Diels-Alder reaction of dienophiles with fatty acids and/or resin acids and allowing the mixture to react. Heating the mixture increases the rate of reaction. The solid product is ground to form a powder. The properties of the drilling fluid that may be improved by adding the soap include filtration control, fluid loss control, emulsification and emulsion stability, and electrical stability.

Abstract: A method of servicing a wellbore in contact with a subterranean formation comprising placing in the wellbore a composition comprising a metal oxide, a soluble salt, a surfactant and an oleaginous fluid, and allowing the composition to set. A method of cementing a wellbore comprising placing a first composition comprising magnesium oxide, a chloride or phosphate salt, an organophilic surfactant and an oleaginous fluid into a wellbore, allowing the composition to set, placing a second cementitious composition into the wellbore, and allowing the second cementitious composition to set. A method of servicing a wellbore comprising placing in the wellbore a composition comprising magnesium oxide, magnesium chloride, an organophilic surfactant, water and an oleaginous fluid wherein the organophilic surfactant is present in an amount of from about 0.

Abstract: Methods and compositions for sealing subterranean zones having temperatures in the range of about 80° F. to about 300° F. are provided. In a method of the invention, a sealing composition of the invention of water, a substantially fully hydrated depolymerized polymer and poly lactic acid, with a pH above about 8.5, is introduced into the subterranean zone wherein it becomes substantially rigid and seals the zone when exposed to subterrnean zone temperatures above about 80° F.

Abstract: A superior powder form of a metallic soap for enhancing the properties of an invert emulsion drilling fluid may be prepared by a dry process saponification reaction. The process includes mixing a source of metal cations with the product of a Diels-Alder reaction of dienophiles with fatty acids and/or resin acids and allowing the mixture to react. Heating the mixture increases the rate of reaction. The solid product is ground to form a powder. The properties of the drilling fluid that may be improved by adding the soap include filtration control, fluid loss control, emulsification and emulsion stability, and electrical stability.

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: Cement compositions that include improved lost circulation materials are provided. In certain exemplary embodiments, the improved lost circulation materials include inelastic particles of polyethylene, polystyrene, and/or polypropylene. Optionally, the cement compositions also may include additives such as fly ash, a surfactant, a dispersant, a fluid loss control additive, a conventional lost circulation material, an accelerator, a retarder, a salt, a mica, fiber, a formation-conditioning agent, fumed silica, bentonite, expanding additives, microspheres, weighting materials, or a defoamer.

Abstract: Wellbore servicing fluids and methods of using the same to service a wellbore in a subterranean formation are provided. A filter cake in the wellbore is contacted with the gravel packing fluid, which comprises an oil-soluble additive capable of removing the filter cake. The additive undergoes hydrolysis to produce an acid upon contacting water provided from, for example, water in the wellbore servicing fluid, connate water in the subterranean formation, water in the filter cake, water produced by the subterranean formation, water pumped into the wellbore, or combinations thereof. The acid dissolves particulates in the filter cake in situ. In an embodiment in which the wellbore servicing fluid serves as a gravel packing fluid, the fluid also deposits gravel along the face of the subterranean formation, forming a barrier against the migration of sand from the formation and into the wellbore.

Abstract: Cementing compositions are provided that comprise water, cement kiln dust, vitrified shale, zeolite, and/or amorphous silica, that utilize a packing volume fraction such that the solid particulate materials of the fluid are in a hindered settling state. Methods of cementing are provided that utilize compositions comprising water, cement kiln dust, vitrified shale, zeolite, and/or amorphous silica, that utilize a packing volume fraction such that the solid particulate materials of the fluid are in a hindered settling state.

Abstract: The present invention provides settable compositions that comprise water and cement kiln dust. The settable compositions optionally may comprise an additive that comprises at least one of the following group: fly ash; shale; slag cement; zeolite; metakaolin; and combinations thereof. The settable compositions optionally may be foamed with a gas. Methods of cementing also are provided that comprise: providing the settable composition; introducing the settable composition into a location to be cemented; and allowing the settable composition to set therein. The location to be cemented may be above ground or in a subterranean formation.

Abstract: Settable drilling fluids comprising an aqueous-based drilling fluid and cement kiln dust. Methods of cementing in a subterranean formation comprising: providing a settable drilling fluid comprising an aqueous-based drilling fluid and cement kiln dust, introducing the settable drilling fluid into a subterranean formation, and allowing the settable drilling fluid to set in the subterranean formation. Methods of converting an aqueous-based drilling fluid to a settable drilling fluid comprising: providing the aqueous-based drilling fluid, and adding cement kiln dust to the aqueous-based drilling fluid to form the settable drilling fluid. Methods of drilling a well bore and cementing a well bore comprising: drilling a well bore, circulating an aqueous-based drilling fluid in the well bore during the step of drilling the well bore, adding cement kiln dust to the aqueous-based drilling fluid to form a settable drilling fluid, and allowing the settable drilling fluid to set in the well bore.

Abstract: A method of cementing in a subterranean formation that comprises providing a foamed cement composition that comprises water, a cement, a gas, and an additive, the additive comprising an anionic foaming agent and at least one of an anionic foam stabilizer or a Zwitterionic foam booster; placing the cement composition into the subterranean formation; and allowing the cement composition to set therein is provided. Foamed cement compositions, additives for foaming and stabilizing a cement composition, and methods of reducing the density of a cement composition, also are provided.

Abstract: Methods of using cement compositions that comprise basalt fibers in subterranean formations are provided. An example of such a method may comprise providing a cement composition that comprises water, a hydraulic cement, and a plurality of basalt fibers; introducing the cement composition into a subterranean formation; allowing the cement composition to set therein. Also provided are methods of cementing a pipe string in a well bore and methods of enhancing the compressive strength of a cement composition.

Abstract: Settable compositions that comprise water, CKD, and microspheres, wherein the lightweight settable composition has a density less than about 13 pounds per gallon. Methods of cementing that comprise providing a lightweight settable composition having a density less than about 13 pounds per gallon, the lightweight settable composition comprising water, CKD, and microspheres, introducing the lightweight settable composition into a location to be cemented and allowing the lightweight settable composition to set therein.

Abstract: For use in estimating or predicting bioaccumulation of a chemical analyte, even a surfactant, log Pow values for the analyte may be determined by calculating the log of the ratio of the concentrations of the analyte in n-octanol and in water, equilibrated using a slow-stir method. In this method, samples of the analyte are prepared and stirred in n-octanol and water (or other largely immiscible solvents) at a rate sufficiently low to avoid emulsions over time at a constant temperature. After stirring, the n-octanol layer and the water layer are sampled and the quantity of analyte in each measured.

Abstract: For use in estimating or predicting bioaccumulation of a chemical analyte, even a surfactant, log Pow values for the analyte may be determined by calculating the log of the ratio of the concentrations of the analyte in n-octanol and in water, equilibrated using a slow-stir method. In this method, samples of the analyte are prepared and stirred in n-octanol and water (or other largely immiscible solvents) at a rate sufficiently low to avoid emulsions over time at a constant temperature. After stirring, the n-octanol layer and the water layer are sampled and the quantity of analyte in each measured.