A method for improving oil recovery within a subterranean formation that includes forming a barrier within the formation to isolate at least a portion of a first region from a proximate second region. The barrier is formed by introducing a first solution including an ammonium containing compound and a second solution including a nitrite containing compound into the formation. The first solution, the second solution, or both, further include a foaming agent. The compounds react to generate nitrogen gas in the presence of the foaming agent to generate a foam within a first region. The foam provides the barrier. Carbon dioxide is introduced into the formation. The barrier diverts the carbon dioxide away from the first region and into the second region. The carbon dioxide operates to displace at least a portion of a hydrocarbon present in the second region and discharge the hydrocarbon from the formation.

The present disclosure may be directed to defoaming methods and compositions. A method of treating a subterranean formation may comprise providing a defoaming composition, wherein the defoaming composition comprises a tall-oil-derived surfactant. The method may further comprise mixing the defoaming composition with an aqueous fluid to form a treatment fluid such that foaming in the treatment fluid is reduced, wherein the treatment fluid is a water-based fluid. The method may further comprise placing the treatment fluid into the subterranean formation.

A method for improving oil recovery within a subterranean formation that includes forming a barrier within the formation to isolate at least a portion of a first region from a proximate second region. The barrier is formed by introducing a first solution including an ammonium containing compound and a second solution including a nitrite containing compound into the formation. The first solution, the second solution, or both, further include a foaming agent. The compounds react to generate nitrogen gas in the presence of the foaming agent to generate a foam within a first region. The foam provides the barrier. Water is introduced into the formation. The barrier diverts the water away from the first region and into the second region. The water operates to displace at least a portion of a hydrocarbon present in the second region and discharge the hydrocarbon from the formation.

Methods and compositions for a foamed treatment fluid in a wellbore. A method of treating a lost circulation zone comprising: introducing a foamed treatment fluid into a lost circulation zone in a subterranean formation, wherein the foamed treatment fluid comprises: a cement; a viscosifying agent; a thixotropic additive; a foaming surfactant; a gas; and water; allowing the foamed treatment fluid to set in the lost circulation zone to seal the lost circulation zone. A foamed treatment fluid comprising: a cement; a viscosifying agent; a thixotropic additive; a foaming surfactant; a gas; and water.

Methods and compositions for a foamed treatment fluid in a wellbore. A method of treating a lost circulation zone comprising: introducing a foamed treatment fluid into a lost circulation zone in a subterranean formation, wherein the foamed treatment fluid comprises: a cement; a viscosifying agent; a thixotropic additive; a foaming surfactant; a gas; and water; allowing the foamed treatment fluid to set in the lost circulation zone to seal the lost circulation zone. A foamed treatment fluid comprising: a cement; a viscosifying agent; a thixotropic additive; a foaming surfactant; a gas; and water.

An elastomer alloy includes a base polymer including hydrogenated nitrile butadiene rubber (HNBR) and at least one secondary polymer, which is at least one of paraffin wax, low-density polyethylene (LDPE), linear low-density polyethylene (LLDPE), high-density polyethylene (HDPE), and a plastomer. The base polymer and the at least one secondary polymer are blended into a polymer matrix. The elastomer alloy also includes a plurality of smart fillers dispersed within the polymer matrix, at least one chemical foaming agent, and a curing activator.

An elastomer alloy includes a base polymer including hydrogenated nitrile butadiene rubber (HNBR) and at least one secondary polymer, which is at least one of paraffin wax, low-density polyethylene (LDPE), linear low-density polyethylene (LLDPE), high-density polyethylene (HDPE), and a plastomer. The base polymer and the at least one secondary polymer are blended into a polymer matrix. The elastomer alloy also includes a plurality of smart fillers dispersed within the polymer matrix, at least one chemical foaming agent, and a curing activator.

Methods of treating a subterranean formation penetrated by a wellbore may include injecting a multistage fracturing treatment into the wellbore comprising one or more stages of geopolymer precursor composition containing a geopolymer precursor and an activator, and one or more stages of a spacer fluid; and curing the one or more stages of geopolymer precursor composition. In another aspect, methods of treating a subterranean formation penetrated by a wellbore may include injecting a multistage fracturing treatment into the wellbore that include one or more stages of geopolymer precursor composition, wherein the geopolymer precursor composition includes an emulsion having an oleaginous external phase, and an internal phase comprising one or more surfactants, a geopolymer precursor, and an activator, and one or more stages of a spacer fluid; and curing the one or more stages of geopolymer precursor composition.

Methods of treating a subterranean formation penetrated by a wellbore may include injecting a multistage fracturing treatment into the wellbore comprising one or more stages of geopolymer precursor composition containing a geopolymer precursor and an activator, and one or more stages of a spacer fluid; and curing the one or more stages of geopolymer precursor composition. In another aspect, methods of treating a subterranean formation penetrated by a wellbore may include injecting a multistage fracturing treatment into the wellbore that include one or more stages of geopolymer precursor composition, wherein the geopolymer precursor composition includes an emulsion having an oleaginous external phase, and an internal phase comprising one or more surfactants, a geopolymer precursor, and an activator, and one or more stages of a spacer fluid; and curing the one or more stages of geopolymer precursor composition.

A chemical packer composition having a polyurethane foam with nanoparticles or micron-sized particles for use as an annular chemical packer in openhole horizontal wells is provided. The chemical packer composition may be used in a horizontal well having a screen (for example, a gravel pack screen) and completed using an openhole completion. The chemical packer composition may include, for example, silica nanoparticles or sand micron-sized particles. The chemical packer composition may be placed in an annulus section defined by the wellbore and the screen that traverses one or more fluid producing zones. In some instances, a portion of the chemical packer composition may be selectively removed to open a fluid producing zone to the wellbore and form plugs blocking other fluid producing zones.