A method may include: introducing a treatment fluid into a subterranean formation, the treatment fluid comprising: an aqueous brine; and a hydrolysable resin precursor; allowing the hydrolysable resin precursor to hydrolyze in the subterranean formation to form at least a polymerizable resin precursor monomer; and allowing the polymerizable resin precursor monomer to polymerize to form a polymerized resin in the subterranean formation.

Methods for servicing a hydrocarbon well using natural gas in a well intervention operation can include preparing a working fluid having a composition containing about 10 wt % to 100 wt % of a gas phase natural gas, where the quantity and composition of the natural gas is selected so that under specified well intervention conditions, the natural gas and a liquid phase recovery target material form a mixture in the condensing vapor-gas or vapor-gas part of the mixture's phase envelope. During the well intervention operation and at the specified well intervention conditions, the method can include injecting the working fluid into the well, contacting the working fluid with the liquid phase recovery target material, vaporizing the recovery target material, and forming a homogeneous gas phase well mixture of the recovery target material and natural gas. At least a portion of the homogenous gas phase well mixture can be recovered at surface.

Methods for servicing a hydrocarbon well using natural gas in a well intervention operation can include preparing a working fluid having a composition containing about 10 wt % to 100 wt % of a gas phase natural gas, where the quantity and composition of the natural gas is selected so that under specified well intervention conditions, the natural gas and a liquid phase recovery target material form a mixture in the condensing vapor-gas or vapor-gas part of the mixture's phase envelope. During the well intervention operation and at the specified well intervention conditions, the method can include injecting the working fluid into the well, contacting the working fluid with the liquid phase recovery target material, vaporizing the recovery target material, and forming a homogeneous gas phase well mixture of the recovery target material and natural gas. At least a portion of the homogenous gas phase well mixture can be recovered at surface.

A lignocellulose nanofibril material, a stable foam system based thereon, a preparation method and an application thereof are provided. The lignocellulosic nanofibril material includes the following components: 0.5-20 wt % of wood flour, 0.1-10 wt % of (2,2,6,6-tetramethylpiperidin-1-yl)oxidanyl, 2-25 mmol/g of an oxidant, 6-15 wt % of NaBr, and the remaining is water. The stable foam system based on the lignocellulosic nanofibril material includes: 0.1-1.0 wt % of the lignocellulosic nanofibril material, 0.2-1.0 wt % of a surfactant, 0.1-10 wt % of sodium chloride, 0.1-1.0 wt % of calcium chloride, 0.1-1.0 wt % of magnesium chloride, 0.1-1.0 wt % of sodium sulfate, and a balance of water.

A method comprising: providing a composition comprising: a base liquid; and solid particles; foaming the composition with a gas to produce a foamed drilling fluid; wherein the foamed drilling fluid is characterized as a Pickering foam wherein at least a portion of the solid particles are dispersed on an interface between the base liquid and the gas to stabilize the Pickering foam; pumping the foamed drilling fluid through a drill string; and extending a wellbore through a subterranean formation.

A method comprising: providing a composition comprising: a base liquid; and solid particles; foaming the composition with a gas to produce a foamed drilling fluid; wherein the foamed drilling fluid is characterized as a Pickering foam wherein at least a portion of the solid particles are dispersed on an interface between the base liquid and the gas to stabilize the Pickering foam; pumping the foamed drilling fluid through a drill string; and extending a wellbore through a subterranean formation.

A method of mitigating annular pressure buildup includes providing or using a foamed treatment fluid including: an aqueous base fluid; a water-soluble polymer comprising carbonyl groups; an organic crosslinking agent that comprises an amine group that is capable of crosslinking the water-soluble polymer comprising carbonyl groups; a foam surfactant; and sufficient gas to form a foam; and introducing the foamed treatment fluid into a well bore annulus. A foamed treatment fluid includes an aqueous base fluid; a water-soluble polymer comprising carbonyl groups; an organic crosslinking agent that comprises an amine group that is capable of crosslinking the water-soluble polymer comprising carbonyl groups; a foam surfactant; and sufficient gas to form a foam.

A method of mitigating annular pressure buildup includes providing or using a foamed treatment fluid including: an aqueous base fluid; a water-soluble polymer comprising carbonyl groups; an organic crosslinking agent that comprises an amine group that is capable of crosslinking the water-soluble polymer comprising carbonyl groups; a foam surfactant; and sufficient gas to form a foam; and introducing the foamed treatment fluid into a well bore annulus. A foamed treatment fluid includes an aqueous base fluid; a water-soluble polymer comprising carbonyl groups; an organic crosslinking agent that comprises an amine group that is capable of crosslinking the water-soluble polymer comprising carbonyl groups; a foam surfactant; and sufficient gas to form a foam.

An omniphobic emulsion comprising an aqueous continuous phase having dispersed therein a plurality of non-aqueous discontinuous phase droplets; wherein the non-aqueous discontinuous phase droplets are characterized by a droplet size of less than about 100 micrometers (m); wherein each of the plurality of non-aqueous discontinuous phase droplets comprises a plurality of surfactant molecules and an omniphobic agent, wherein each surfactant molecule has a hydrophilic head portion and a hydrophobic tail portion; wherein each of the plurality of non-aqueous discontinuous phase droplets comprises the plurality surfactant molecules having the hydrophilic head portions disposed into a droplet outer layer with the hydrophobic tail portions extending inward from the droplet outer layer toward the omniphobic agent; and wherein the droplet outer layer encloses the omniphobic agent.

The present application provides a gas-generating aqueous fluid containing a gas-generating compound like an azo compound, and an organic amine like a primary, secondary or tertiary amine, a hydrazine, a hydrazide, or a semicarbazide. The aqueous fluid may also a viscosifier, and a foaming surfactant. The present application also provides a method of using the gas-generating composition to modulate density of a wellbore fluid for use in downhole applications. The method optionally includes adding an oxidizer to the wellbore fluid.