Abstract: A process to prepare a solid cement composition; includes adding a meltable compound to an aqueous slurry of cement and; mixing until a homogeneous dispersion is obtained. The dispersion is placed in a mould, where the dispersion is set by hydration. Part of the meltable compound is melted at a temperature range of which the maximum is above the melting point of the meltable compound and a minimum below the melting point of the meltable compound. A material, either still as a dispersion or an already setting cement is exposed to heat development or a temperature gradient such that the temperature is at least above the congealing point of the meltable compound to obtain a solid cement composition.

Abstract: Slugs of a cement slurry and of a resin composition are injected into an underground wellbore. The resin composition contains at least a curable resin, a filler, a swelling agent, a curing initiator, and a crosslinking retarding agent. The curing initiator activates the curing in response to temperature. The crosslinking retarding agent delays curing of the resin, to permit pumping the composition into the wellbore. After injection, the cement slurry and resin composition are allowed to cure, to create a stacked cement and cured resin column that provides a zonal isolation seal within the wellbore. The resin composition may suitably be an elastomer-forming composition. The cured resin may be swellable by allowing contact with a wellbore fluid.

Abstract: Recovering oil from a subterranean formation is disclosed, comprising processing a source water to produce a processed water stream and a reject water stream; injecting a first fluid into an injection well toward a first downhole exhaust, wherein the first fluid comprises the processed water stream; and injecting a second fluid into the injection well toward a second downhole exhaust, wherein the second fluid comprises the reject water stream or a produced water stream, wherein the first fluid is separated from the second fluid within the injection well; and producing oil via a production well.

Abstract: The invention concerns a method of applying a coating in a liquid state to wellbore tubing, such as threaded connector parts or casing sections, before running the tubing downhole. The coating only cures while running downhole. The coating is an elastic curable coating composition, comprising a curable elastic thermosetting resin, a curing agent and a water-absorbing expansion agent. During make-up of a connector, the liquid coating composition acts as lubricant. When cured, the coating will swell when contacted with a wellbore fluid to ensure leak-tightness.

Abstract: Recovering oil from a subterranean formation is disclosed, comprising processing a source water to produce a processed water stream and a reject water stream; injecting a first fluid into an injection well toward a first downhole exhaust, wherein the first fluid comprises the processed water stream; and injecting a second fluid into the injection well toward a second downhole exhaust, wherein the second fluid comprises the reject water stream or a produced water stream, wherein the first fluid is separated from the second fluid within the injection well; and producing oil via a production well.

Abstract: The invention concerns a method of applying a coating in a liquid state to wellbore tubing, such as threaded connector parts or casing sections, before running the tubing downhole. The coating only cures while running downhole. The coating is an elastic curable coating composition, comprising a curable elastic thermosetting resin, a curing agent and a water-absorbing expansion agent. During make-up of a connector, the liquid coating composition acts as lubricant. When cured, the coating will swell when contacted with a wellbore fluid to ensure leak-tightness.

Abstract: A method of providing an annular seal around a tubular in a wellbore penetrating a subsurface formation, the method comprising providing a tubular in the wellbore, wherein an annular space (18) is formed around the tubular; providing an annular gravel pack in the annular space; wherein the method further comprises arranging a band (9a, 9b, 9c, 9d) of gel-forming material around the tubular before providing the annular gravel pack, wherein the gel-forming material is swellable in a selected fluid, and wherein the annular seal is formed by contacting the band of gel-forming material with the selected fluid; and a wellbore system comprising a gravel-packed tubular in a wellbore, wherein the tubular is provided with a band of gel-forming material in a layer around the tubular, the band being surrounded by gravel (15), and wherein the gel-forming material is swellable in a selected fluid.

Abstract: A system for injecting a treatment fluid into a well, the system includes: a surface controlled subsurface safety valve; a valve control conduit which extends from the surface controlled subsurface safety valve to a wellhead of the well, wherein the surface controlled subsurface safety valve is controlled by varying the fluid pressure in the valve control conduit; a fluid injection opening in the valve control conduit effective for discharging treatment fluid into the well; a treatment fluid injection conduit arranged which is connected to the valve control conduit; at least one treatment fluid injection opening; and a one way check valve which prevents fluid flow from each treatment fluid injection opening via the treatment fluid injection conduit into the valve control conduit, wherein the treatment fluid injection conduit is arranged into a section of the well which is located below the surface controlled subsurface safety valve such that at least one treatment fluid injection opening is located below the

Abstract: A method of treating an underground formation is provided, the method including sequential steps of:(a) contacting the formation with an aqueous medium;(b) contacting the formation with a hydrocarbon fluid;(c) contacting the formation with a solvent in the form of a glycol ether;(d) contacting the formation with a consolidation solution of between 30 and 60 % m of monomeric and/or polymeric organic polyepoxides having more than one epoxy group per molecule and between 5 and 20% m of a curing agent in the solvent; and(e) contacting the formation with a viscosified fluid containing aliphatic hydrocarbons.