The present disclosure relates to systems and methods for using aldehydes as a catalyst for oxidative breakers. An embodiment of the present disclosure is a method comprising: providing a treatment fluid that comprises: an aqueous base fluid, a polymeric gelling agent, a breaker that comprises an oxidative salt, and a catalyst that comprises an aldehyde; allowing the breaker to interact with the polymeric gelling agent; and allowing the viscosity of the treatment fluid to reduce.

A method including introducing a treatment fluid into a subterranean formation having a downhole temperature in the range of between about 60° C. to about 95° C. The treatment fluid comprises an aqueous fluid, a swelling agent, and an oxidizing agent. Forming a diverter plug at a first permeable zone in the subterranean formation with the swelling agent, and breaking at least a portion of the swelling agent with the oxidizing agent.

A gravel pack containing a substrate particle coated with an inducibly degradable and a porous particle having an internal interconnected porosity that is at least partially infused with an inducer material for dissolving of a layer of filter cake disposed between the gravel pack and a subterranean formation.

In accordance with one or more embodiments, this disclosure describes a viscoelastic fluid for a subterranean formation comprising: viscoelastic surfactant comprising the general formula:

##STR00001##

where R.sub.1 is a saturated or unsaturated hydrocarbon group of from 17 to 29 carbon atoms, R.sub.2 and R.sub.3, are each independently selected from a straight chain or branched alkyl or hydroxyalkyl group of from 1 to 6 carbon atoms; R.sub.4 is selected from H, hydroxyl, alkyl or hydroxyalkyl groups of from 1 to 4 carbon atoms; k is an integer of from 2-20; m is an integer of from 1-20; and n is an integer of from 0-20; brine solution; and at least one nanoparticle viscosity modifier comprising a particle size of 0.1 to 500 nanometers, or 0.1 to 100 nanometers.

In accordance with one or more embodiments, this disclosure describes a viscoelastic surfactant fluid for a subterranean formation comprising: brine solution; at least one polyacrylamide viscosity modifier with a weight averaged molecular weight (Mw) from 250,000 g/mol to 40,000,000 g/mol; and a viscoelastic surfactant according to formula (I):

##STR00001##

where R.sub.1 is a saturated or unsaturated hydrocarbon group of from 17 to 29 carbon atoms, R.sub.2 and R.sub.3 are each independently selected from a straight chain or branched alkyl or hydroxyalkyl group of from 1 to 6 carbon atoms; R.sub.4 is selected from H, hydroxyl, alkyl or hydroxyalkyl groups of from 1 to 4 carbon atoms; k is an integer of from 2-20; m is an integer of from 1-20; and n is an integer of from 0-20.

The invention relates to a hydrocarbon recovery composition comprising one or more internal olefin sulfonates and/or one or more alkoxylated alcohols and/or alkoxylated alcohol derivatives and a method of recovering hydrocarbons from a hydrocarbon formation comprising feeding a hydrocarbon recovery composition into the formation, allowing the hydrocarbon recovery composition to contact the formation for a period of time, and withdrawing a mixture of the hydrocarbon recovery composition and hydrocarbons from the formation.

A breaker composition comprising: (i) an acid precursor, (ii) a delaying agent and (iii) an aqueous fluid wherein the breaker composition has an effective operating temperature range of from about 25° C. to about 180° C. A wellbore servicing system comprising (a) an aqueous-based drilling fluid, wherein the aqueous-based drilling fluid forms water-wet solids in the wellbore; and (b) a breaker composition comprising (i) an acid precursor, (ii) a delaying agent and (iii) an aqueous fluid. A method of dissolving a filtercake comprising contacting the filtercake with a breaker solution comprising (i) an acid precursor, (ii) a delaying agent and (iii) an aqueous fluid wherein the filtercake comprises calcium carbonate.

Treatment chemicals (for example, scale inhibition chemicals) can be applied to fluids in a pipeline by diverting a side stream of the produced water from a pipeline into a vessel containing a solid material to release of an active fluid treatment agent from the solid material into the diverted produced water; merging the diverted produced fluid containing the active fluid treatment agent into the pipeline; and adjusting a flow rate of the diverted side stream of the produced water to change a level of the active fluid treatment agent in the flow of produced water in the pipeline. Treatment systems can include a pipeline, a vessel containing a solid treatment material; a bypass line providing a fluid connection between the pipeline and an inlet of the vessel; and a return line providing a fluid connection between an outlet of the vessel and the pipeline.

Compositions and methods are provided for delayed breaking of viscoelastic surfactant gels inside subterranean formations. Breaking is accomplished without mechanical intervention or use of a second fluid. The delayed breaking agent is a hydrophobically modified alkali swellable emulsion polymer, which can be a copolymer comprising acidic monomers, nonionic monomers, and associative monomers. The viscoelastic surfactant can be a zwitterionic surfactant, and can be selected from the group consisting of sultaines, betaines, and amidoamine oxides.

Methods of preparing a viscosified treatment fluid comprising a base fluid, a gelling agent, and breaker coated particulates (“BCPs”). The BCPs comprise particulates at least partially coated with a first layer of a stabilization agent followed by a second layer of a breaker. The viscosified treatment fluid may be introduced into a subterranean formation, the breaker activated to reduce a viscosity thereof, and a particulate pack formed in the subterranean formation with the BCPs.