A carbon nanoparticle and methods of making and using a carbon nanoparticle are provided. The carbon nanoparticle includes a reaction product of an organic reactant, an alkoxy amine, and an organometallic compound. The organometallic compound includes an element selected from the group consisting of a rare earth element, a transition metal element, and combinations thereof, and the carbon nanoparticle includes from 0.5 to 50 wt. % of the element. A method of making the carbon nanoparticle is also provided. The method includes combining the organic reactant, the alkoxy amine, and the organometallic compound into a mixture and heating the mixture such that the carbon nanoparticle forms. A method of determining a flow characteristic of a formation or an attribute of a fluid in a formation using the carbon nanoparticle is also provided.

A carbon nanoparticle and methods of making and using a carbon nanoparticle are provided. The carbon nanoparticle includes a reaction product of an organic reactant, an alkoxy amine, and an organometallic compound. The organometallic compound includes an element selected from the group consisting of a rare earth element, a transition metal element, and combinations thereof, and the carbon nanoparticle includes from 0.5 to 50 wt. % of the element. A method of making the carbon nanoparticle is also provided. The method includes combining the organic reactant, the alkoxy amine, and the organometallic compound into a mixture and heating the mixture such that the carbon nanoparticle forms. A method of determining a flow characteristic of a formation or an attribute of a fluid in a formation using the carbon nanoparticle is also provided.

A method and system using the measured adsorption of a tracer substance leached from a flexible liner sealing a subterranean borehole to indicate the flow of fluid, typically water, past the borehole. The liner is provided with contaminant collectors. The liner is impregnated in its fabrication with a tracer substance. The tracer is leached from the liner as water flows past the liner in/from fractures in the surrounding geologic formation. The water containing any leached tracer may also flow past the collectors. The collectors adsorb the tracer relative to the amount of tracer leached from the liner and into the passing water, and the concentration of tracer in the flowing water is proportional to the amount of toluene leached from the liner. The tracer level in a collector is tested as an indication of the flow past the liner.

A method and system using the measured adsorption of a tracer substance leached from a flexible liner sealing a subterranean borehole to indicate the flow of fluid, typically water, past the borehole. The liner is provided with contaminant collectors. The liner is impregnated in its fabrication with a tracer substance. The tracer is leached from the liner as water flows past the liner in/from fractures in the surrounding geologic formation. The water containing any leached tracer may also flow past the collectors. The collectors adsorb the tracer relative to the amount of tracer leached from the liner and into the passing water, and the concentration of tracer in the flowing water is proportional to the amount of toluene leached from the liner. The tracer level in a collector is tested as an indication of the flow past the liner.

A well bore logging tool for measuring a pore fluid property of a hydrocarbon reservoir that may include, a tool housing, a vessel containing a tracer, a launcher attached to the vessel that may be configured to inject a tracer into the hydrocarbon reservoir. The well bore logging too may further include a retrieval device configured to extract at least a portion of the tracer from the hydrocarbon reservoir. The well bore logging too may further include a storage canister may be configured to store a portion of the tracer extracted from the hydrocarbon reservoir, and a scanning device may be configured to read a value of at least one fluid saturation property detected by the tracer. The vessel, launcher, retrieval device, storage canister, and scanning device may be enclosed in a tool housing.

A well bore logging tool for measuring a pore fluid property of a hydrocarbon reservoir that may include, a tool housing, a vessel containing a tracer, a launcher attached to the vessel that may be configured to inject a tracer into the hydrocarbon reservoir. The well bore logging too may further include a retrieval device configured to extract at least a portion of the tracer from the hydrocarbon reservoir. The well bore logging too may further include a storage canister may be configured to store a portion of the tracer extracted from the hydrocarbon reservoir, and a scanning device may be configured to read a value of at least one fluid saturation property detected by the tracer. The vessel, launcher, retrieval device, storage canister, and scanning device may be enclosed in a tool housing.

A method, a system, tools for use by the system, and an interpretation method for injecting and detecting tracers and conducting flow characterizing of a petroleum well are disclosed. The method describes monitoring of travel time and slip velocity between two/three different phases (oil/water and possibly gas) in the well. The travel time and slip velocity are determined using an injection too for injection of an over pressurized injection of the partitioning tracers each of which would follow certain phase. The tracers are detected by an optical detection probe in the pipe. The slip velocity is obtained from the difference of travel time of two tracers which partition to two different phases.

A method, a system, tools for use by the system, and an interpretation method for injecting and detecting tracers and conducting flow characterizing of a petroleum well are disclosed. The method describes monitoring of travel time and slip velocity between two/three different phases (oil/water and possibly gas) in the well. The travel time and slip velocity are determined using an injection too for injection of an over pressurized injection of the partitioning tracers each of which would follow certain phase. The tracers are detected by an optical detection probe in the pipe. The slip velocity is obtained from the difference of travel time of two tracers which partition to two different phases.

A method for determining a location and trajectory for a new wellbore relative to an adjacent wellbore includes: receiving controllable variable data and uncontrollable variable data related to fracturing a formation by a stimulation operation in a first wellbore penetrating the formation; receiving pressure communication event or pressure non-communication event identification data related to identification of a pressure communication event or pressure non-communication event in a second wellbore penetrating the formation in response to the fracturing; extracting features from the controllable and uncontrollable variable data to provide extracted features; detecting a pressure communication event using the extracted features and the pressure communication event or pressure non-communication event identification data using an analytic technique; identifying one or more quantified causes of the detected pressure communication event using an artificial intelligence technique; and determining the location and trajectory of the new wellbore using the one or more quantified causes.

A method for determining a location and trajectory for a new wellbore relative to an adjacent wellbore includes: receiving controllable variable data and uncontrollable variable data related to fracturing a formation by a stimulation operation in a first wellbore penetrating the formation; receiving pressure communication event or pressure non-communication event identification data related to identification of a pressure communication event or pressure non-communication event in a second wellbore penetrating the formation in response to the fracturing; extracting features from the controllable and uncontrollable variable data to provide extracted features; detecting a pressure communication event using the extracted features and the pressure communication event or pressure non-communication event identification data using an analytic technique; identifying one or more quantified causes of the detected pressure communication event using an artificial intelligence technique; and determining the location and trajectory of the new wellbore using the one or more quantified causes.