A method of monitoring a fluid is described comprising: introducing a tracer into the fluid and analysing the fluid to determine if the tracer is present in the fluid; characterised in that the tracer comprises luminescent carbon-based nanoparticles exhibiting a peak luminescence intensity at an emission wavelength of at least 500 nm. The method is in particular a method of monitoring a parameter of a hydrocarbon well, pipeline or formation. A use of a tracer and a tracer composition comprising carbon-based nanoparticles exhibiting a peak luminescence intensity at an emission wavelength of at least 500 nm are also described.

A hydrocarbon formation treatment micellar solution fluid and its use in treating underperforming hydrocarbon formations is described and claimed. A hydrocarbon formation treatment micellar solution fluid wherein the micellar solution fluid comprises water, a non-terpene oil-based moiety, a brine resistant aqueous colloidal silica sol; and optionally a terpene or a terpenoid, wherein the brine resistant aqueous colloidal silica sol has silica particles with a surface that is functionalized with at least one moiety selected from the group consisting of a hydrophilic organosilane, a mixture of hydrophilic and hydrophobic organosilanes, or a polysiloxane oligomer, wherein the brine resistant aqueous colloidal silica sol passes at least two of three of these brine resistant tests: API Brine Visual, 24 Hour Seawater Visual and API Turbidity Meter, and wherein, when a terpene or terpenoid is present, the ratio of total water to terpene or terpenoid is at least about 15 to 1.

A system and process for defining, blending and monitoring fresh water with subterranean produced formation fluids, with particular constituents of the blended waters being controlled for proper use in gel-type hydraulic fracturing operations. On-site measurements and calculations of clay stabilization replacement, through a Potassium Chloride (KCl) Equivalency calculation, provide feedback on water constituent adjustments that may be needed just prior to the gel-based hydraulic fracturing process. This assures adequate gel cross-linking times, delayed gel cross-linking times, and clay stabilization in the formation to be fractured.

Systems and methods include using a fracture fluid downhole for fracturing a formation. The method includes providing an aqueous solution comprising dissolved solids at a certain ionic strength, and adding a proppant to create a fracture fluid. The method continues by adding a polymeric additive and a surfactant to the fracture fluid, wherein the polymeric additive comprises friction reducing capabilities that can be decreased by the ionic strength present in the fracture fluid (i.e., ionic strength originally found in the water). The addition of the polymeric additive and the surfactant to the fracture fluid creates an enhanced fracture fluid, wherein the surfactant increases the performance of the friction reducing capabilities of the polymeric additive in the enhanced fracture fluid, which provides a more efficient fracturing operation. The method concludes by pumping the enhanced fracture fluid downhole for a more efficient fracture of the formation.

Methods are disclosed for emplacing a gel-form material in a porous subterranean formation, such as a hydrocarbon reservoir. The material is formed by admixing solid nanoparticles with gelation supporting amounts of surfactants or ionic species, such as ionic species of the kind that form ionic liquids. The nanoparticle to ion ratio may be selected, in combination with selecting the components of the gel-form material, so that the rheological and gelation properties of the gel-form material are adapted for a particular use, for example forming a fluid flow barrier in a reservoir.

In wellbore servicing fluids and methods related thereto a Pickering emulsion is produced by mixing silica, an oleaginous fluid, an aqueous base fluid and an emulsifier. The silica can comprise a silica dust and larger proppant particles that work together to form a Pickering emulsion with the proppant particles suspended therein. In some embodiments, the proppant particles are a silica sand.

A method of fracturing a subterranean formation may comprise: pumping a fracturing fluid into the subterranean formation, through a wellbore, at or above a fracture gradient of the subterranean formation, wherein the fracturing fluid comprises halloysite nanotubes.

Gas hydrates are formed in treatment fluid in situ within the wellbore. Foaming of the treatment fluid can occur both during the introduction of the gas treatment fluid to form hydrates and downhole near the subterranean reservoir where the heat of the reservoir will cause the gas hydrates to revert back to a gaseous state. The method involves preparing a treatment fluid comprising an aqueous base fluid, and a viscosifying agent at the surface. This treatment fluid is then introduced into the wellbore. Also, at the surface, a liquefied natural gas is pressurized and then vaporized to produce a vaporized natural gas. The vaporized natural gas is introduced into the wellbore so as to mix with the treatment fluid also being introduced. The introduction is such that gas hydrates are formed from the natural gas in the treatment fluid in situ within the wellbore.

Provided is a method and composition for the in-situ generation of synthetic sweet spots in tight-gas formations. The composition can include gas generating compounds, which upon activation, exothermically react to generate heat and gas. The method of using the composition includes injecting the composition into a tight-gas formation such that upon activation, the heat and gas are generated, resulting in the formation of fractures and microfractures within the formation.

Provided is a method and composition for the in-situ generation of synthetic sweet spots in tight-gas formations. The composition can include gas generating compounds, which upon activation, exothermically react to generate heat and gas. The method of using the composition includes injecting the composition into a tight-gas formation such that upon activation, the heat and gas are generated, resulting in the formation of fractures and microfractures within the formation.