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The carrier particles received in each zone of the well include nano-sized particles that are chemically unique to that zone. Fines migration has been troublesome during oil and gas production, as well as during many oil and gas recovery operations including, but not necessarily limited to, acidizing, fracturing, gravel packing, secondary and tertiary recovery operations, and the like. The particulate additive, also referred to herein as nano-sized particles or nanoparticles may fixate or flocculate fines, such as clay and non-clay particles to keep or restrict or reduce the fine particles from moving in, for example, a propped hydraulic fracture in a subterranean formation. As defined herein, fines (i.e. formation fines) are naturally occurring particles having particle size less than 37 microns (μm). As discussed in SPE 81017 referred to above, most of the fines that migrate and cause damage have a charge, and most clay particles generally have an overall negative charge. Detecting such nanoparticles is useful in situations where a well has more than one zone, such as sequential multi-stage fracturing treatments in horizontally completed shale or tight gas completions. Nano-sized particles like magnesium oxide (MgO) may be used to fixate formation fines such as clay and quartz in subterranean hydrocarbon formations to inhibit, restrain, or prevent the fines from migrating to near-wellbore regions to damage production of the hydrocarbons. In this non-limiting example, the nano-sized particles, which coat on the proppant particles, may bind or fix the fines to the proppant particles, such as 20/40 mesh ceramic proppants, so that both the formation fines and the nanoparticles remain on the proppant particles and do not travel or are restrained to the point that fine migration damage to the near-wellbore region is minimized. Should for some reason carrier particles placed during a treatment, such as proppant within a fracture hydraulic fracturing, be produced or flow back into the wellbore they may be detected via the composition of the nano-size particulate additive and/or via a traceable taggant that may be incorporated into the body of the nano-size particulate additive, coated thereon, or both. Since the nano-sized particles for each zone may carry a unique taggant and/or may themselves be unique, the zone from which the nanoparticles were produced may be determined. And if the nano-sized particles from one or more of the zones should flow back into the wellbore on produced proppant particles (or other carrier particle), a sample of the produced proppant containing the uniquely-tagged and/or unique nanoparticles may be analyzed to determine the identity of the nanoparticle(s)/taggant(s). For instance, for each zone in the well, fines-fixing nanoparticles are introduced into the zone, where the nano-sized particles may carry a detectable taggant that is unique to that zone and/or the nano-sized particle itself may be unique to that zone.
Some nano-sized particles, also called nanoparticles herein, not only have high surface areas compared to their small sizes, but also have relatively high surface charges that permit them to associate or connect other particles together, including other charged particles, but also other non-charged particles. In one non-limiting embodiment, these associations or connections between the fines and the nano-sized particles are due to electrical attractions and other intermolecular forces or effects. Matters are further complicated if a well has more than one zone. For instance, operations such as fracturing, gravel packing, and frac-packing may fail allowing undesired flow back or production of carrier particles such as proppant or gravel particles into the wellbore from, for example, the hydraulic fracture in the formation. If there is a failure in a dual or multi-zonal well it may be very difficult to determine which zone failed. These types of zones may be formed in a sequence where one zone is hydraulically fractured, and once completed another zone is hydraulically fractured and completed, the pattern repeating until all frac jobs for the particular well are finished. For instance, nanoparticles may be disposed on carrier particles such as proppant, sand, gravel, and the like. Embodiments, however, are not limited to the forgoing example, and zones are not limited to fracture-based zones-they may be characterized by any type of interval, such as without limitation gravel pack and frac-pack based zones. In one non-limiting example, the subterranean formation proximate a wellbore may be treated with more than one fracture treatment, each fracture area corresponding with a zone. The nano-sized particles used to fixate formation fines and inhibit, restrain, or prevent such fines from migrating may also be used to identify a defective zone in a well having more than one zone. In embodiments where the nano-sized particles do not include taggant material, each zone receives proppant carrying nanoparticles with a chemical make-up that is distinct for that zone. One example of a fracture completion system is FRAC-POINT, which is available from Baker Hughes Incorporated. In addition to fines migration being troublesome during oil and gas production and/or recovery operations, one or more of these operations may periodically fail. The nanoparticles may or may not be tagged with a detectable material. As such, the intended treatment may not be effective and the produced proppant or gravel or the like may cause additional damage such as to the equipment. Such zones may be termed “fracture-based zones”.
This application is a continuation-in-part application of U.S. The migration of fines involves the movement of fine clay and/or non-clay particles (e.g. quartz, amorphous silica, feldspars, zeolites, carbonates, salts and micas) or similar materials within a subterranean reservoir formation due to drag and other forces during production of hydrocarbons or water. Pat. No. 7,550,413, which in turn claims the benefit of U.S. Ser. No. 11/849,820 filed Sep. 4, 2007, the latter which claims the benefit of U.S. Ser. No. 11/125,465 filed May 10, 2005, issued Mar. 18, 2008, as U.S. Fines migration may result from an unconsolidated or inherently unstable formation, or from the use of an incompatible treatment fluid that liberates fine particles. Hydrocarbons sometimes exist in reservoirs in subterranean rock formations. Provisional Patent Application 60/570,601 filed May 13, 2004 and is a continuation-in-part application of U.S. Non-limiting embodiments as described herein relate to methods and compositions utilizing dual-function nano-sized particles, and more particularly relate, in non-limiting embodiments, to methods and compositions using nano-sized particles effective at reducing fines migration within subterranean formations, and if there is undesired flow back from one or more zones in a well having more than one zone, identifying the zone or zones from which the undesired flow back originated, or both during hydrocarbon recovery operations. The better the connectivity of the pores in the formation (permeability), the better the hydrocarbon production. Fines migration is a complex phenomenon governed largely by mineralogy, permeability, salinity and pH changes, as well as drag forces created by flow velocity, turbulence and fluid viscosity, as described in detail in J. Hibbeler, et al., “An Integrated Long-Term Solution for Migratory Fines Damage,” SPE 81017, SPE Latin 
The authors note that mobilization of fines can severely damage a well’s productivity, and that fines damage is a multi-parameter, complex issue that may be due to one or more of the following downhole phenomena: (1) high flow rates, particularly abrupt changes to flow rates; (2) wettability effects, (3) ion exchange; (4) two-phase flow, particularly due to turbulence that destabilize fines in the near-wellbore region; and (5) acidizing treatments of the wrong type or volume which can cause fines. However, they note that clay particles may become oil-wet or partially oil-wet, due to an outside influence, and thus the fines and clay particles may become attracted to and immersed in the oil phase. When the applied pump rates and pressures are reduced or removed from the formation, the crack or fracture cannot close or heal completely because the high permeability proppant keeps the crack open. The authors also note that all clays have an overall negative charge and that during salinity decrease, pH increases in-situ due to ion exchange. Gravel packing is a sand-control method employed to prevent the production of formation sand. The propped crack or fracture provides a high permeability path connecting the producing wellbore to a larger formation area to enhance the production of hydrocarbons. J. Hibbeler, et al. Fines fixation has become troublesome during oil and gas production and during many oil and gas recovery operations, such as acidizing, fracturing, gravel packing, and secondary and tertiary recovery procedures. Once the crack or cracks are made, high permeability proppant, relative to the formation permeability, is pumped into the fracture to prop open the crack. As pH increases, surface potential of fines increases until de-flocculation and detachment occurs, aggravating fines migration. A pH increase may also be induced via an injected fluid. Hydraulic fracturing is a method of using pump rate and hydraulic pressure to fracture or crack a subterranean formation.