Abstract: Aqueous and substantially anhydrous fluids having particularly low thermal conductivities and variable densities are disclosed. The fluids include: one or more organic and/or inorganic salts and at least one aprotic polar organic solvent, a mixture of aprotic and protic polar organic solvents, and/or a polar organic solvent having both protic and aprotic polar functional group linkages. The fluids optionally include one or more viscosifying agents and are free of cross-linking agents. Methods for formulating and using the fluids are also disclosed.

Abstract: Petroleum coke or coal coke is gasified to produce a gas stream containing carbon monoxide, hydrogen, hydrogen sulfide, and optionally ammonia, carbon dioxide, water, and nitrogen. Carbon monoxide, hydrogen, and hydrogen sulfide, and optionally ammonia, carbon dioxide, water, and nitrogen are separated from the gas stream. The separated carbon monoxide and hydrogen are reacted to produce methanol, and the methanol is reacted with the separated hydrogen sulfide to produce dimethyl sulfide.

Abstract: Aqueous and substantially anhydrous fluids having particularly low thermal conductivities and variable densities are disclosed. The fluids include: one or more organic and/or inorganic salts and at least one aprotic polar organic solvent, a mixture of aprotic and protic polar organic solvents, and/or a polar organic solvent having both protic and aprotic polar functional group linkages. The fluids optionally include one or more viscosifying agents and are free of cross-linking agents. Methods for formulating and using the fluids are also disclosed.

Abstract: A system and process are provided for recovering petroleum from a formation. An oil recovery formulation comprising at least 75 mol % dimethyl sulfide that is first contact miscible with a liquid petroleum composition is introduced into a petroleum bearing formation and petroleum is produced from the formation.

Abstract: A system and process are provided for recovering petroleum from a formation. An oil recovery formulation comprising at least 75 mol % dimethyl sulfide that is first contact miscible with a liquid petroleum composition is introduced into a subterranean petroleum bearing formation comprising heavy oil, extra heavy oil, or bitumen, and petroleum is produced from the formation.

Abstract: A method involving exposing a substance to a promoter, the promoter being made from a liquid carrier and a metal salt component, the metal salt component, having at least (i) a magnetic susceptability above 1000 or (ii) an ionization potential below about 500 volts, or (iii) both (i) and (ii), and applying electromagnetic wave energy to the substance while the substance is in the presence of the promoter, for a period of time and at a frequency and amplification sufficient to promote the modification of at least one physical property of the substance. A related method of treating a well in a subterranean formation, a tank or a pipeline, and the well treatment promoter composition, are also described.

Abstract: Aqueous and substantially anhydrous fluids having particularly low thermal conductivities and variable densities are disclosed. The fluids include: one or more organic and/or inorganic salts and at least one aprotic polar organic solvent, a mixture of aprotic and erotic polar organic solvents, and/or a polar organic solvent having both prone and aprotic polar functional group linkages. The fluids optionally include one or more viscosifying agents and are free of cross-linking agents. Methods for formulating and using the fluids are also disclosed.

Abstract: This invention relates to an aqueous-swellable and degradable diverting system and the use of the system in treating a subterranean formation penetrated by a wellbore. The diverting system comprises a carrier fluid and a partially dehydrated or anhydrous borate source material that does not swell or does not swell substantially when placed in contact with the carrier fluid. The carrier fluid is capable of carrying and placing the borate source material into a stimulation network substantially distanced from a wellbore. The carrier fluid may be a non-aqueous fluid, or when the average size of the borate source material is sufficient large, the carrier fluid may also be an aqueous fluid. Exposure of the diverting composition to sufficient amount of aqueous fluid swells the borate source material, bridges a desired portion of the stimulation network and then dissolves at least a portion of the diverting composition.

Abstract: Many methods are provided including a method comprising: providing a surfactant gel having a first viscosity that comprises an aqueous base fluid and a surfactant; providing an ortho ester breaker; contacting the surfactant gel with the ortho ester breaker; allowing the ortho ester breaker to hydrolyze to produce an acid and an alcohol; and allowing the acid and/or the alcohol to interact with the surfactant gel so as to reduce the first viscosity of the surfactant gel to a second viscosity.

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: A method comprising contacting a zwitterionic surfactant, co-surfactant, and water to form a microemulsifier, and contacting the microemulsifier with an oleaginous fluid under low shear conditions to form a microemulsion. A method comprising introducing a first wellbore servicing fluid comprising at least one oleaginous fluid into a wellbore, wherein the first wellbore servicing fluid forms oil-wet solids and/or oil-wet surfaces in the wellbore, and contacting the oil-wet solids and/or oil-wet surfaces in the wellbore with a second wellbore servicing fluid comprising a zwitterionic surfactant, a co-surfactant, and a brine to form a microemulsion.

Abstract: The invention provides a method for treating tight gas sand and shale subterranean formations, the method comprising: forming a solvent-surfactant blend by combining a solvent, a surfactant and a co-surfactant; adding a diluent to the solvent-surfactant blend to form a micro emulsion; wherein the wettability of the formation altered from water-wet to gas-wet, and the amount of water imbibed into the formation is reduced.

Abstract: A method comprising contacting a zwitterionic surfactant, co-surfactant, and water to form a microemulsifier, and contacting the microemulsifier with an oleaginous fluid under low shear conditions to form a microemulsion. A method comprising introducing a first wellbore servicing fluid comprising at least one oleaginous fluid into a wellbore, wherein the first wellbore servicing fluid forms oil-wet solids and/or oil-wet surfaces in the wellbore, and contacting the oil-wet solids and/or oil-wet surfaces in the wellbore with a second wellbore servicing fluid comprising a zwitterionic surfactant, a co-surfactant, and a brine to form a microemulsion.

Abstract: Embodiments of the present invention relate to delivering a slurry having a fracturing fluid and one or more proppants to a fracture in a subterranean formation. At least one proppant has PPS and produces less than 5 weight percent fines at a closure pressure of the fractured subterranean formation as determined by API RP 60. The one or more proppants are deposited into the fracture to prop the fracture.

Abstract: A method for shortening the shear recovery time of cationic, zwitterionic, and amphoteric viscoelastic surfactant fluid systems by adding an effective amount of an amphiphilic polymeric rheology enhancer containing at least one portion that is a partially hydrolyzed polyvinyl ester or partially hydrolyzed polyacrylate. The rheology enhancer also increases fluid viscosity and very low rheology enhancer concentration is needed. Preferred surfactants are betaines and quaternary amines. The fluids are useful in oilfield treatments, for example fracturing and gravel packing.

Abstract: Improved methods and compositions for consolidating proppant in subterranean fractures are provided. In certain embodiments, the hardenable resin compositions may be especially suited for consolidating proppant in subterranean fractures having temperatures above about 200° F. Improved methods include providing proppant particles coated with a hardenable resin composition mixed with a gelled liquid fracturing fluid, and introducing the fracturing fluid into a subterranean zone. The fracturing fluid may form one or more fractures in the subterranean zone and deposit the proppant particles coated with the resin composition therein. Thereafter, the hardenable resin composition on the proppant particles is allowed to harden by heat and to consolidate the proppant particles into degradation resistant permeable packs. The hardenable resin composition may include a liquid bisphenol A-epichlorohydrin resin, a 4,4?-diaminodiphenyl sulfone hardening agent, a solvent, a silane coupling agent, and a surfactant.

Abstract: This invention relates to divinyl sulfone crosslinking agents, viscosified treatment fluids, and methods of using these compositions in applications wherein viscosified treatment fluids may be used. In one embodiment, this invention provides a method of treating a portion of a subterranean formation comprising: providing a viscosified treatment fluid that comprises an aqueous base fluid and a crosslinked gelling agent, the crosslinked gelling agent comprising at least one alkyl sulfone bridge, and treating the portion of the subterranean formation.

Abstract: Liquids comprised solely of anions and cations (“ionic liquids”) are disclosed as novel components of fluids (and techniques relying upon those fluids) for stimulation of hydrocarbon wells. In particular, the fluids disclosed are useful in matrix acidizing. Formation of the ionic liquids of the present Invention is highly exothermic, hence the heat generated can be used, for instance, to melt de-watered drilling fluid in the near-wellbore region of the formation. Further, reaction of the ionic liquids with water results in acid generation; this acid can be used to, for instance, to stimulate a formation, either by conventional matrix acidizing or fracture acidizing. In addition, certain preferred species of the ionic liquids of the present Invention are highly stable solvents, hence they can be used as carrier fluids for highly reactive super acids (e.g., SbF5+HF) in connection with matrix acidizing.

Abstract: An acid corrosion inhibitor composition is provided for petroleum wells and water wells subjected to stimulation with acid solutions. The inhibitor combines cinnamaldehyde and an organo-sulfur compound. The inhibitor provides a reduced rate of corrosion and fewer instances of pitting than inhibitors which include cinnamaldehyde alone. The inhibitor does not suffer from the well-known oil field aldehyde/polyacrylamide crosslinking incompatibility. The enhanced performance by the inhibitor of the present invention is provided by a synergistic action between the cinnamaldehyde and an organo-sulfur compound.

Abstract: A process which can be used to dissolve sulfur deposits or sulfur plugs in gas wells, oil wells, vessels, or conduits for transporting a fluid containing sulfur is provided. The process comprises contacting the sulfur deposits or sulfur plugs under conditions sufficient to dissolve sulfur wherein the composition comprises an organic sulfide, a base, a surfactant, and optionally, a mercaptan and is present in an amount effective to dissolve sulfur.