Included are methods and systems for enhancing recovery of a hydrocarbon fluid. An example method includes selecting a liquefied natural gas capable of being processed into a modified liquefied natural gas having a desired composition and adjusting the composition of the liquefied natural gas to provide the modified liquefied natural gas with the desired composition. The method further includes preparing a treatment fluid from the modified liquefied natural gas, introducing the treatment fluid into a wellbore, and contacting the hydrocarbon fluid with the treatment fluid in the wellbore.

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 of treating a subterranean formation by contacting the formation with the following: (a) ammonium sulfamate; (b) an oxidizing agent selected from a perchlorate or a nitrite or combinations thereof; and (c) an acid.

Hydraulic fracturing fluids and methods to hydraulically fracture a subterranean formation and oxidize organic material in the subterranean formation. The hydraulic fracturing fluid includes water, another fluid, and a surfactant. An inorganic oxidizer is included in the water.

A method of stimulating a hydrocarbon-bearing formation may include generating a foamed fracturing fluid having a half-life of 160 to 300 min at 77° F. The foamed fracturing fluid may comprise a fluorosurfactant, a nanoparticle, and a gas phase. The method may then include introducing the foamed fracturing fluid into a hydrocarbon-bearing formation under a pressure greater than the fracturing pressure of the hydrocarbon-bearing formation to generate fractures in the hydrocarbon-bearing formation. Another method of stimulating a hydrocarbon-bearing formation may include introducing a foaming composition into the hydrocarbon-bearing formation under a pressure greater than fracturing pressure of the hydrocarbon-bearing formation to generate fractures in the hydrocarbon-bearing formation. The foaming composition may include a fluorosurfactant, a nanoparticle, and a gas phase. The method then may include generating a foam from the foaming composition inside the hydrocarbon-bearing formation. The foam may have a half-life of 160 to 300 min at 77° F.

Methods of fracturing a subterranean formation containing a hydrocarbon include introducing a first fracturing fluid that includes natural gas into the formation at a rate and pressure sufficient to create a complex fracture in the formation; introducing a second fracturing fluid into the formation, wherein the second fracturing fluid comprises water, a gelling agent, a foaming agent, natural gas, and proppant particulates; and allowing the second fracturing fluid to transport a portion of the proppant particulates into the complex fracture.

Described herein is a multi-phase aqueous composition containing a surfactant; a first phase comprising water, an acid, and a water-soluble acid retarding agent; and a second phase selected from the group consisting of an immiscible organic phase, a gas, and combinations thereof. Further described are methods of making and using such compositions.

Stabilized foams are provided, adapted in particular for subterranean applications in hydrocarbon recovery operations. The foams are stabilized with surfactant-decorated nanoparticles, and the decoration of the nanoparticles with surfactant may be titrated to tune the stabilization of the foam.

A method of treating a subterranean formation by contacting the formation with the following: (a) ammonium compound; (b) an oxidizing agent selected from a perchlorate or a nitrite or combinations thereof; and (c) sulfamic acid.

A method of treating a subterranean formation by contacting the formation with the following: (a) an ammonium compound; (b) an oxidizing agent selected from a perchlorate or a nitrite or combinations thereof; and (c) one or more acids, at least one of which is a bisulfate salt.