Abstract: A fracturing system for a well, in which a stream of LPG, a mixture of propane and butane, is injected into the well at frac pressure. Proppant is supplied into the LPG stream, and carried by the LPG mix into the formation. Inert gas such as nitrogen is used for purging system components of LPG, and to help protect against risk of explosion. Nitrogen may also be added to the LPG mix during a frac of shale gas or coal gas formations.

Abstract: A fracturing system for a well, in which a stream of LPG, a mixture of propane and butane, is injected into the well at frac pressure. Proppant is supplied into the LPG stream, and carried by the LPG mix into the formation. Inert gas such as nitrogen is used for purging system components of LPG, and to help protect against risk of explosion. Nitrogen may also be added to the LPG mix during a frac of shale gas or coal gas formations.

Abstract: A method of processing liquefied petroleum gas used in a treatment fluid previously injected into a hydrocarbon reservoir is disclosed, the method comprising: recovering at least a portion of the treatment fluid from the hydrocarbon reservoir to produce recovered treatment fluid; and separating liquefied petroleum gas in the form of a gas or liquid from the recovered treatment fluid using a separator. An apparatus for processing liquefied petroleum gas used in a treatment fluid previously injected into a hydrocarbon reservoir is also disclosed, the apparatus comprising: a separator; a recovery line for recovering treatment fluid from the hydrocarbon reservoir, the recovery line connected to supply recovered treatment fluid to the separator, the separator being to separate a liquefied petroleum gas portion in gas or liquid form from the recovered treatment fluid.

Abstract: A fracturing system for a well, in which a stream of LPG, a mixture of propane and butane, is injected into the well at frac pressure. Proppant is supplied into the LPG stream, and carried by the LPG mix into the formation. Inert gas such as nitrogen is used for purging system components of LPG, and to help protect against risk of explosion. Nitrogen may also be added to the LPG mix during a frac of shale gas or coal gas formations.

Abstract: Methods of tailoring a hydrocarbon fracturing fluid for a subterranean formation are disclosed. Fluid in the subterranean formation has a fluid temperature. A first critical temperature of a hydrocarbon fluid is adjusted to a critical temperature above the fluid temperature by adding a liquefied petroleum gas component to the hydrocarbon fluid to produce the hydrocarbon fracturing fluid. The liquefied petroleum gas component has a second critical temperature, and the hydrocarbon fluid comprises liquefied petroleum gas. A hydrocarbon fracturing fluid made by these methods are also disclosed. Methods of treating a subterranean formation are also disclosed. A hydrocarbon fracturing fluid is introduced into the subterranean formation, the hydrocarbon fracturing fluid having a critical temperature that is above a fluid temperature of the hydrocarbon fracturing fluid when the hydrocarbon fracturing fluid is in the subterranean formation.

Abstract: Methods of tailoring a hydrocarbon fracturing fluid for a subterranean formation are disclosed. Fluid in the subterranean formation has a fluid temperature. A first critical temperature of a hydrocarbon fluid is adjusted to a critical temperature above the fluid temperature by adding a liquefied petroleum gas component to the hydrocarbon fluid to produce the hydrocarbon fracturing fluid. The liquefied petroleum gas component has a second critical temperature, and the hydrocarbon fluid comprises liquefied petroleum gas. A hydrocarbon fracturing fluid made by these methods are also disclosed. Methods of treating a subterranean formation are also disclosed. A hydrocarbon fracturing fluid is introduced into the subterranean formation, the hydrocarbon fracturing fluid having a critical temperature that is above a fluid temperature of the hydrocarbon fracturing fluid when the hydrocarbon fracturing fluid is in the subterranean formation.

Abstract: A fracturing system for a well, in which a stream of LPG, a mixture of propane and butane, is injected into the well at frac pressure. Proppant is supplied into the LPG stream, and carried by the LPG mix into the formation. Inert gas such as nitrogen is used for purging system components of LPG, and to help protect against risk of explosion. Nitrogen may also be added to the LPG mix during a frac of shale gas or coal gas formations.

Abstract: In the field of drilling lateral channels from the cased bore of an oil well, a system is presented whereby a number of lateral channels can be drilled through the casing and out a distance into the formation with no requirement to move or raise the lateral drilling apparatus to the surface for each lateral channel drilled. The direction of the drilled lateral channel can be selected by the system operator at the well head. The system will allow the drilling of lateral channels with the well under pressure. A configuration is shown which will allow the installation of a flexible perforated liner in the channel, which flexible perforated liner will prevent the material around the channel from collapsing.

Abstract: A wax and asphaltene solvation fluid for use in oil and gas wells is derived as a residual fluid from a feedstock that includes a greater mass percentage of trimethylbenzene than decane, and is preferably sour. Mass percentage of both aromatics and asphaltenes in the residual fluid is in the 30%-70% range, and a complex mixture of both is described.

Abstract: A wax and asphaltene solvation fluid for use in oil and gas wells is derived as a residual fluid from a feedstock that includes a greater mass percentage of trimethylbenzene than decane, and is preferably sour. Mass percentage of both aromatics and asphaltenes in the residual fluid is in the 30%-70% range, and a complex mixture of both is described.

Abstract: A well fracturing system in which a fracturing fluid storage vessel, high pressure pump and high pressure conduit are connected in series to a well. A pressure vessel is connected to the high pressure conduit for injecting proppant carrying fracturing fluid into the well without the proppant carrying fracturing fluid passing through the high pressure pump. The pressure vessel may be formed of a pipe with a free floating piston dividing the pressure vessel into a drive side and driven side. Proppant carrying fracturing fluid is stored in the driven side, and may be emplaced within the pressure vessel at a remote site from the well. Drive fluid is injected into the drive side to force the proppant carrying fracturing fluid into the high pressure conduit and down the well. The drive fluid may be a diverted portion of fracturing fluid pumped by the high pressure pumper. Several pressure vessels may be used in parallel, and proppant may be stratified in the pressure vessel.

Abstract: A well treatment fluid comprising a mixture of (A) a major amount of a first hydrocarbon fluid, the first hydrocarbon fluid being composed predominantly of diaromatics and triaromatics having more than 16 carbon atoms, and (B) a minor amount of a second hydrocarbon fluid, the second hydrocarbon fluid being composed predominantly of hydrocarbons having from 7 to 12 carbon atoms. The mixture preferably has a density greater than 1000 kg/m.sup.3 at 15.degree. C. and a viscosity lower than 30 centiStokes at 20.degree. C. In a method according to the invention, a kill fluid is formed by mixing the first and second hydrocarbon fluids to produce a hydrocarbon mixture, preferably having a viscosity of less than 30 centiStokes at 20.degree. C. and a density above 1000 kg/m.sup.3 at 15.degree. C.

Abstract: A wax and asphaltene solvation fluid for use in oil and gas wells is derived as a residual fluid from a feedstock that includes a greater mass percentage of trimethylbenzene than decane, and is preferably sour. Mass percentage of both aromatics and asphaltenes in the residual fluid is in the 30%-70% range, and a complex mixture of both is described.

Abstract: Linear olefin monomers, and particularly alpha-olefins, having a pour point greater than -102.degree., a flash point greater than 10.degree. and a boiling point greater than 121.degree. are proposed as frac fluids in treatment of oil and gas wells by fracturing. Linear olefin monomers are injected into the well, and fracturing pressures applied to the well to fracture the well. Linear olefin monomers may be mixed with a liquified drive fluid such as CO.sub.2, preferably with the CO.sub.2 forming a miscible bank ahead of the linear olefin monomers for use in driving the load fluid from the well.

Abstract: A method of improving oil or gas well productivity from a well penetrating a formation in an oil or gas reservoir, by injecting a stream of liquified drive fluid into the well ahead of a load fluid to establish a miscible bank of drive fluid in the well. While injecting the stream of liquified drive fluid into the well, a load fluid in which the liquified drive fluid is miscible is injected into the well mixed with the liquified drive fluid. The ratio of liquified drive fluid to load fluid is initially at a level sufficient to form a miscible bank of drive fluid in the gaseous state ahead of the load fluid in the well. Subsequently, the ratio of liquified drive fluid to load fluid injected into the well is reduced.

Abstract: A method of improving oil or gas well productivity from a well penetrating a formation in an oil or gas reservoir, by forming a load fluid by obtaining a hydrocarbon fluid containing a known percentage of aromatics and adding an amount of CO.sub.2 to the hydrocarbon fluid that is determined according to a predetermined miscibility relationship between the CO.sub.2 and the hydrocarbon fluid that establishes the amount of CO.sub.2 required to form a bank of CO.sub.2 ahead of the load fluid in the formation. The load fluid is applied to the well at a pressure such that CO.sub.2 in load fluid within the well bore remains in solution and CO.sub.2 in load fluid within the formation leaks off the load fluid into the formation and forms a bank of CO.sub.2 ahead of the load fluid. The surface pressure is released from the load fluid and the load fluid flows back out of the well. The miscibility relationship between CO.sub.2 and hydrocarbon based load fluids depends on the aromatic content of the load fluid.

Abstract: A fire retarded solvent composition includes a mixture of at least one flammable organic solvent; and a mixture of at least one brominated hydrocarbon, in an amount sufficient to decrease the flame propagation rate of the composition and preferably increase the flash point of the solvent composition. The brominated hydrocarbon may be selected from the group consisting of dibromoethane, dibromomethane, chlorodibromomethane, bromochloromethane, dibromodifluoromethane, dibromodifluoroethane, 1,2,dibromo-1.1-difluoroethane, chlorodibromofluoromethane, 1,2dibromotetrafluoroethane and 1,2dibromoethylene. Dibromomethane and bromochloromethane are preferred. When used as an oil and gas operation fluid, the fluorinated hydrocarbons should not be used, nor should the brominated hydrocarbon be an aromatic or contain an oxygen bridge. The organic solvent is preferably selected from the group consisting of light petroleum distillate, diesel and crude, the fluid hydrocarbon primarily having between 5 and 12 carbon atoms.