Methods of fracturing a subterranean formation include introducing a fracturing fluid containing an aqueous medium, a viscosifying agent and a polyethylene oxide alkyl ether through a wellbore and into the subterranean formation, pressurizing the fracturing fluid to fracture the subterranean formation, and allowing the fracturing fluid to flow back into the wellbore from the subterranean formation. The polyethylene oxide alkyl ether useful in some embodiments is defined according to the formula: ##STR00001##
where R.sub.1 and R.sub.2 are independently selected from linear or branched alkyl groups having from 2 to 16 carbon atoms, and n may be a value selected from within a range of from 1 to 100.

A method includes introducing a polymer composite particle including a degradable polymer and a color masterbatch into a stimulation fluid; injecting the stimulation fluid into an opening of the subterranean formation; maintaining the polymer composite particle inside the opening during which the polymer composite particle is exposed to moisture at a downhole temperature, where moisture degrades the degradable polymer blend over a period of 20 to 60 days and produces a tracer; recovering produced gas including the tracer from the subterranean formation; determining the tracer in the produced gas; and correlating the tracer to the opening of the subterranean formation. A composition includes a polymer composite particle of a degradable polymer and a color masterbatch and stimulation fluid. A method includes blending a degradable polymer with a color masterbatch to provide a degradable polymer blend in a polymer composite particle and introducing the polymer composite particle into a stimulation fluid.

A composition for use in well stimulation operations, the composition comprising a saline fluid, the saline fluid comprising between 50,000 ppm and 70,000 ppm; a polymer, the polymer operable to react with a crosslinker to increase a viscosity of the saline fluid; a zirconium crosslinker, the zirconium crosslinker operable to react with the polymer; and a chelating agent, the chelating agent comprises L-glutamic acid N, N diacetic acid (GLDA), wherein the GLDA is present in an amount between 1 wt % and 8 wt %.

A composition for use in well stimulation operations, the composition comprising a saline fluid, the saline fluid comprising between 50,000 ppm and 70,000 ppm; a polymer, the polymer operable to hydrate in the saline fluid such that it increases the viscosity of the saline fluid react with a chelating agent, the chelating agent comprises L-glutamic acid N, N diacetic acid (GLDA), wherein the GLDA is present in an amount between 1 wt % and 20 wt %.

A polymer breaking solution usable in fracking and other downhole applications comprises a solution of aqueous hydrogen peroxide, an anionic surfactant, a metal chelating agent, an acidic pH buffer, a soluble zinc compound, and in some embodiments, a viscosifying agent. In other embodiments, the solution may additionally comprise a linear hydrophobic surfactant. At treatment concentrations of between 500 ppm to 1,500 ppm, the solution is non-toxic and usable at a wide range of downhole temperatures (32 C. to 82 C.).

A method for monitoring gas production in a subterranean formation includes introducing a polymer composite particle having a degradable polymer blend and a tracer into a stimulation fluid, where the degradable polymer blend includes a polymer blend of a first degradable polymer and a second degradable polymer; injecting the stimulation fluid including the polymer composite particle into a treatment zone including one opening, where the polymer composite particle remains and is exposed to moisture at downhole temperature which degrades the degradable polymer blend in 7 to 15 days; recovering produced gas which includes the tracer; determining a presence of the tracer; and correlating the presence of the tracer to the treatment zone. A composition includes a polymer composite particle of a degradable polymer blend of a first degradable polymer of polyester, polyester copolymers, and combinations thereof and a second degradable polymer of polyamide, a tracer, and a stimulation fluid.

A method for tracing gas flow in a hydrocarbon reservoir with compositions including a degradable polymer and a detectable component. An exemplary method includes introducing a tracer composition at a first location in the reservoir, contacting the tracer composition with the reservoir to hydrolyze the degradable polymer, and detecting a degraded tracer composition including the hydrolyzed polymer and the detectable component in a gas sample collected at a second location in the reservoir.

A composition for use in well stimulation operations, the composition comprising a saline fluid, the saline fluid comprising between 50,000 ppm and 70,000 ppm; a polymer, the polymer operable to react with a crosslinker to increase a viscosity of the saline fluid; a zirconium crosslinker, the zirconium crosslinker operable to react with the polymer; and a chelating agent, the chelating agent comprises L-glutamic acid N, N diacetic acid (GLDA), wherein the GLDA is present in an amount between 1 wt % and 8 w t %.

A method for monitoring gas production in a subterranean formation includes introducing a polymer composite particle having a degradable polymer blend and a tracer into a stimulation fluid, where the degradable polymer blend includes a polymer blend of a first degradable polymer and a second degradable polymer; injecting the stimulation fluid including the polymer composite particle into a treatment zone including one opening, where the polymer composite particle remains and is exposed to moisture at downhole temperature which degrades the degradable polymer blend in 7 to 15 days; recovering produced gas which includes the tracer; determining a presence of the tracer; and correlating the presence of the tracer to the treatment zone. A composition includes a polymer composite particle of a degradable polymer blend of a first degradable polymer of polyester, polyester copolymers, and combinations thereof and a second degradable polymer of polyamide, a tracer, and a stimulation fluid.

A well treatment composition may include a capsule and a treatment agent solution within the capsule. The treatment agent solution may have a treatment agent. The system may include a radiation source: neutron, gamma, X-ray, and/or ultraviolet. A method may include introducing the well treatment composition downhole in wellbore circulation fluid, and introducing a radiation source into the wellbore and positioning the radiation source. The method may include activating the radiation source and emitting radiation that intermingles with the well treatment composition at a target location. The method may include maintaining the wellbore to allow emitted radiation from the activated radiation source to react with the well treatment composition, forming a radiation activated well treatment composition. The method may include allowing the radiation activated well treatment composition to disintegrate or dissolve, breaking encapsulation and releasing treatment agent at the target location.