Abstract: Compositions and methods for determining the origin location of a subterranean sample are provided. Compositions include a nanoparticle tag including a superparamagnetic iron oxide core, an intermediate layer including a fluorescent dye, and a polymer shell. The nanoparticles can be synthesized by functionalizing a superparamagnetic iron oxide nanoparticle core and covalently bonding a fluorescent dye to the functionalized nanoparticle core. In some implementations, a polymer is covalently bonded to the functionalized, fluorescent superparamagnetic iron oxide nanoparticle core. The nanoparticle tag can be used to determine the origin location of a subterranean sample by mixing the nanoparticle tag into a fluid, flowing the fluid into a subterranean formation, recovering subterranean samples from the subterranean formation, and separating tagged samples from untagged samples using a magnet.

Abstract: A method of treating a subsurface formation with a coated proppant includes introducing the first hydraulic fracturing composition into a wellbore and the subsurface formation through a first zone of the plurality of zones of the subsurface formation; propagating at least one subsurface fracture in the first zone with the first hydraulic fracturing composition, and wherein the hydraulic fracturing composition includes a fluid medium and a first coated proppant dispersed within the fluid medium, the first coated proppant including: a particulate substrate; a first polymeric layer surrounding the particulate substrate, the first polymeric layer including a first chemical additive; and a second polymeric layer surrounding the first polymeric layer, the second polymeric layer including a first chemical tracer, the first chemical tracer including barcoded degradable polymers, fluorescent dyes, quantum dot nanoparticles, paramagnetic nanoparticles, up-conversion phosphors, long-persistent phosphors, or time-resolve

Abstract: A coated proppant including a particulate substrate, a first polymeric layer surrounding the particulate substrate, and a second polymeric layer surrounding the first polymeric layer. The first polymeric layer may include chemical additives. The second polymeric layer may include chemical tracers. The chemical tracers include barcoded degradable polymers, fluorescent dyes, quantum dot nanoparticles, superparamagnetic nanoparticles, up-conversion phosphors, long-persistent phosphors, time-resolved fluorescence resonance energy transfer polymer-nanoparticles (TR-FRET), or combinations thereof.

Abstract: Optical properties of a tracer in water are measured at varying concentrations. A reference curve is built based on the measured optical properties at varying concentrations. An emulsion is mixed with the tracer. The emulsion is demulsified into an oil component and an aqueous component. Optical properties of one of the components are measured. A partition coefficient is determined based on the measured optical properties of a demulsified component and the reference curve.

Abstract: A method of quantifying zonal flow in a multi-lateral well is described. A first taggant is flowed to a first lateral, and a second taggant is flowed to a second lateral. A first produced fluid that includes the first taggant is flowed from the first lateral into a production tubing. A second produced fluid that includes the second taggant is flowed from the second lateral into the production tubing. A produced stream including the first produced fluid and the second produced fluid is flowed uphole through the production tubing. An amount of the first taggant and an amount of the second taggant in the produced stream are measured. Production of fluid from the multi-lateral well proceeds without ceasing throughout the method.

Abstract: Optical properties of a tracer in water are measured at varying concentrations. A reference curve is built based on the measured optical properties at varying concentrations. An emulsion is mixed with the tracer. The emulsion is demulsified into an oil component and an aqueous component. Optical properties of one of the components are measured. A partition coefficient is determined based on the measured optical properties of a demulsified component and the reference curve.

Abstract: A method of preparing an enhanced oil recovery composition is described. The method includes carbonizing a biomass waste material to provide carbon microparticles. The method includes functionalizing the carbon microparticles through an acid treatment such that the carbon microparticles have a hydrophilic surface. The method further includes grinding the carbon microparticles to provide carbon nanoparticles, where the carbon nanoparticles have a hydrophilic surface and a hydrophobic surface. A method of enhanced oil recovery is also described.

Abstract: Devices for chemical analysis include a first separation element formed on the substrate, the first separation element having a wicking surface that separates water from hydrocarbons in a fluid sample, a hydrophobic barrier at least partially surrounding the first separation element, a second separation element fluidically connected the first separation element, the second separation element configured to trap salts and organic matter present in the fluid sample, and a detection element fluidically connected to the second separation element, the detection element having a surface that binds with one or more analytes that may be present in the fluid sample and thereby emits a signal that is capable of being optically detected by a detector. Methods include providing such a device for chemical analysis, placing the fluid sample on the first separation element, and detecting the signal emitted by the detection element.

Abstract: The disclosure relates to compositions, methods and systems that include gel particles that include a tag. The gel particles can be used to label drill cuttings generated during a drilling operation.

Abstract: A method for reducing condensate in a subsurface formation is disclosed. The method includes introducing a reactive mixture including an aqueous solution, urea, dopamine, a silica nanoparticle precursor, a silane grafting compound, and an alcohol compound into the subsurface formation. The method also includes allowing generation of ammonia through thermal decomposition of the urea and allowing the silica nanoparticle precursor to hydrolyze, thereby forming silica nanoparticles. The method further includes allowing the silane grafting compound to graft onto the silica nanoparticles, thereby forming functionalized silica nanoparticles. The method also includes allowing polymerization of the dopamine, thereby forming polydopamine. The method also includes allowing the functionalized silica nanoparticles to attach to the subsurface formation via the polydopamine, thereby reducing condensate in the subsurface formation.

Abstract: A system and method for quantifying zonal flow in a multi-lateral well, including providing a first taggant through a first dosing tubing to a first lateral in a wellbore of the multi-lateral well, providing a second taggant through a second dosing tubing to a second lateral in the wellbore, flowing a first produced fluid from a subterranean formation via the first lateral into production tubing, flowing a second produced fluid including from the subterranean formation via the second lateral into the production tubing, flowing a produced stream including the first produced fluid and the second produced fluid uphole through the production tubing and discharging the produced stream from the wellbore, and analyzing the produced stream to measure an amount of the first taggant in the produced stream and an amount of the second taggant in the produced stream, wherein the first taggant and the second taggant are water soluble.

Abstract: A method, system, and taggants (tracers) for quantifying zonal flow in a multi-lateral well having a wellbore with a first lateral and second lateral. The technique includes flowing first produced fluid from a formation via the first lateral into production tubing providing a first taggant through a first dosing tubing to the first lateral, and flowing second produced fluid from the formation via the second lateral into the production tubing and providing a second taggant through a second dosing tubing to the second lateral. A produced stream having the first produced fluid and the second produced fluid flows uphole through the production tubing and discharges from the wellbore. The produced stream may be analyzed to measure an amount of the first taggant in the produced stream and an amount of the second taggant in the produced stream.

Abstract: A coated proppant including a particulate substrate, a first polymeric layer surrounding the particulate substrate, and a second polymeric layer surrounding the first polymeric layer. The first polymeric layer may include chemical additives. The second polymeric layer may include chemical tracers. The chemical tracers include barcoded degradable polymers, fluorescent dyes, quantum dot nanoparticles, superparamagnetic nanoparticles, up-conversion phosphors, long-persistent phosphors, time-resolved fluorescence resonance energy transfer polymer-nanoparticles (TR-FRET), or combinations thereof.

Abstract: A method of treating a subsurface formation with a coated proppant includes introducing the first hydraulic fracturing composition into a wellbore and the subsurface formation through a first zone of the plurality of zones of the subsurface formation; propagating at least one subsurface fracture in the first zone with the first hydraulic fracturing composition, and wherein the hydraulic fracturing composition includes a fluid medium and a first coated proppant dispersed within the fluid medium, the first coated proppant including: a particulate substrate; a first polymeric layer surrounding the particulate substrate, the first polymeric layer including a first chemical additive; and a second polymeric layer surrounding the first polymeric layer, the second polymeric layer including a first chemical tracer, the first chemical tracer including barcoded degradable polymers, fluorescent dyes, quantum dot nanoparticles, paramagnetic nanoparticles, up-conversion phosphors, long-persistent phosphors, or time-resolve

Abstract: Systems and methods for analyzing groundwater samples with multiple organic tracer species from a petroleum containing reservoir include obtaining the sample, isolating an aqueous fraction of the groundwater sample, separating the aqueous fraction into a plurality of components, where each component corresponds to a different one of the organic tracer species, combining each of the separated components with at least one lanthanide element to form a plurality of component solutions, where a ratio of the at least one lanthanide element to the separated component in each component solution is 5:1 or greater, and analyzing each component solution to determine a relative amount of each organic tracer species in the groundwater sample.

Abstract: Compositions and methods for determining the origin location of subterranean rock samples. In some implementations, the compositions include a nanoparticle tag that includes a natural polysaccharide, a fluorescent dye, and superparamagnetic nanoparticles. In some implementations, a method of determining the origin location of a subterranean rock sample includes mixing the nanoparticle tag into a fluid, flowing the fluid into a subterranean formation, recovering subterranean rock samples from the formation, separating tagged rock samples from untagged rock samples using a magnet, and determining the origin location by analyzing a fluorescent signal of the nanoparticle tag.

Abstract: Compositions and methods for determining the origin location of a subterranean rock sample. Compositions include a nanoparticle tag with a fluorescent core and a polymer shell. The fluorescent core can include up-converting nanoparticles, rare earth element doped oxide, long persistent fluorescent materials, or encapsulated lanthanide complexes. Methods include mixing a nanoparticle tag into a fluid, flowing the fluid through a work string into a subterranean formation, recovering subterranean rock samples from the subterranean formation, and determining an origin location of the subterranean rock sample by detecting the presence of the nanoparticle tag on the sample.

Abstract: The disclosure features methods of analyzing a fluid extracted from a reservoir, the methods including introducing a first composition featuring a first complexing agent into a reservoir at a first location, extracting a fluid from the reservoir at a second location different from the first location, combining the fluid with a second composition featuring a concentration of a lanthanide ion to form a third composition featuring a concentration of a complex formed by the first complexing agent and the lanthanide ion, exposing a quantity of the complex to electromagnetic radiation for a first time period ending at a time t0, detecting fluorescence emission from the quantity of the complex for a second time period starting at a time t1>t0, where t1?t0 is greater than 2 microseconds, and determining information about a fluid flow path between the first location and the second location.

Abstract: Enhanced oil recovery (EOR) including with a lamellar phase having Janus nanoparticles, petroleum surfactant, crude oil, and water and with additional water to give the flooding fluid that may be pumped through a wellbore into a subterranean formation to affect a property of hydrocarbon in the subterranean formation via contact of the flooding fluid with the hydrocarbon.

Abstract: A method, system, and taggants (tracers) for quantifying zonal flow in a multi-lateral well having a wellbore with a first lateral and second lateral. The technique includes flowing first produced fluid from a formation via the first lateral into production tubing providing a first taggant through a first dosing tubing to the first lateral, and flowing second produced fluid from the formation via the second lateral into the production tubing and providing a second taggant through a second dosing tubing to the second lateral. A produced stream having the first produced fluid and the second produced fluid flows uphole through the production tubing and discharges from the wellbore. The produced stream may be analyzed to measure an amount of the first taggant in the produced stream and an amount of the second taggant in the produced stream.