Abstract: Embodiments of the invention provide an untethered apparatus for measuring properties along a subterranean well. According to at least one embodiment, the untethered apparatus includes a housing, and one or more sensors configured to measure data along the subterranean well. The data includes one or more physical, chemical, geological or structural properties in the subterranean well. The untethered apparatus further includes a processor configured to control the one or more sensors measuring the data and to store the measured data, and a transmitter configured to transmit the measured data to a receiver arranged external to the subterranean well. Further, the untethered appratus includes a controller configured to control the buoyancy or the drag of the untethered apparatus to control a position of the untethered apparatus in the subterranean well. The processor includes instructions definining measurement parameters for the one or more sensors of the untethered apparatus within the subterranean well.

Abstract: An untethered apparatus for measuring properties along a subterranean well includes a housing, and one or more sensors configured to measure data along the subterranean well. The data includes one or more physical, chemical, geological or structural properties in the subterranean well. The untethered apparatus further includes a processor configured to control the one or more sensors measuring the data and to store the measured data, and a transmitter configured to transmit the measured data to a receiver arranged external to the subterranean well. Further, the untethered apparatus includes a controller configured to control the buoyancy or the drag of the untethered apparatus to control a position of the untethered apparatus in the subterranean well. The processor includes instructions defining measurement parameters for the one or more sensors of the untethered apparatus within the subterranean well.

Abstract: Systems, apparatuses, and computer-implemented methods are provided for the sensing and prediction of properties of source rock. Disclosed here is a method of predicting the maturity of a source rock that includes obtaining a plurality of data of a sample source rock from a plurality of data acquisition devices placed in vicinity of the sample source rock and analyzing the received data using a predictive correlation to determine maturity of the sample source rock. The predictive correlation is generated by applying a machine learning model to correlate the plurality of data acquired from a plurality of representative source rocks with a plurality of properties of the plurality of representative source rocks.

Abstract: An apparatus for determining properties of an uncharacterized downhole fluid. The apparatus comprises an oscillation driver circuit comprising an amplifier having an output and an input, a feedback loop between the output and input of an amplifier or a logic gate, an electromechanical resonator disposed within the feedback loop such that a the resonator is driven by the oscillation driver circuit, wherein a resonant frequency of the resonator defines an oscillation frequency of the oscillator circuit, and a switch device for causing the oscillator circuit to stop driving the resonator, which thereby enables observation of a decay rate of the oscillation of the electromechanical resonator within the uncharacterized fluid. The electromechanical resonator is enclosed in a conductive layer to protect the resonator against capacitive effects of the downhole fluid.

Abstract: A method of determining a risk of corrosion and scale formation of tubing in a wellbore includes receiving, from a plurality of first sensors positioned at a downhole location of a wellbore, first production stream information and receiving, from a plurality of second sensors positioned at an uphole location, second production stream information. The method also includes performing a material balance to determine a first value representing a difference between a first production steam flow rate at the downhole location and a second production stream flow rate at the uphole location. The method also includes determining a second value representing a critical metal ion concentration of the production stream and, based on a result of comparing the first value with a threshold and based on the second value, determining a third value representing a risk of corrosion and scale formation at the tubing disposed within the wellbore.

Abstract: A method and device are described for making in situ measurements of the density and viscosity of downhole fluids at subterranean wells. An oscillator circuit is deployed in the well comprising an amplifier, a feedback loop, and an electromechanical resonator. The electromechanical resonator is a component in the feedback loop of the oscillator circuit, and has a resonance mode that determines the frequency of the oscillator circuit. The electromechanical resonator is also in contact with the fluid such that the density and viscosity of the fluid influence the resonant frequency and damping of the resonator. The frequency of the oscillator is measured by a microcontroller. In one embodiment, the oscillator circuit periodically stops driving the electromechanical resonator such that the oscillation decays and the rate of decay is also measured by the microcontroller. The density and viscosity of the fluid are determined from the frequency and rate of decay of the oscillation.

Abstract: Embodiments of the invention provide an untethered apparatus for measuring properties along a subterranean well. According to at least one embodiment, the untethered apparatus includes a housing, and one or more sensors configured to measure data along the subterranean well. The data includes one or more physical, chemical, geological or structural properties in the subterranean well. The untethered apparatus further includes a processor configured to control the one or more sensors measuring the data and to store the measured data, and a transmitter configured to transmit the measured data to a receiver arranged external to the subterranean well. Further, the untethered appratus includes a controller configured to control the buoyancy or the drag of the untethered apparatus to control a position of the untethered apparatus in the subterranean well. The processor includes instructions defining measurement parameters for the one or more sensors of the untethered apparatus within the subterranean well.

Abstract: A method of determining a risk of corrosion and scale formation of tubing in a wellbore includes receiving, from a plurality of first sensors positioned at a downhole location of a wellbore, first production stream information and receiving, from a plurality of second sensors positioned at an uphole location, second production stream information. The method also includes performing a material balance to determine a first value representing a difference between a first production steam flow rate at the downhole location and a second production stream flow rate at the uphole location. The method also includes determining a second value representing a critical metal ion concentration of the production stream and, based on a result of comparing the first value with a threshold and based on the second value, determining a third value representing a risk of corrosion and scale formation at the tubing disposed within the wellbore.

Abstract: An untethered apparatus for measuring properties along a subterranean well. According to at least one embodiment, the untethered apparatus includes a housing, and one or more sensors configured to measure data along the subterranean well. The data includes one or more physical, chemical, geological or structural properties in the subterranean well. The untethered apparatus further includes a processor configured to control the one or more sensors measuring the data and to store the measured data, and a transmitter configured to transmit the measured data to a receiver arranged external to the subterranean well. Further, the untethered apparatus includes a controller configured to control the buoyancy or the drag of the untethered apparatus to control a position of the untethered apparatus in the subterranean well. The processor includes instructions defining measurement parameters for the one or more sensors of the untethered apparatus within the subterranean well.

Abstract: The present disclosure describes methods and systems for determining source rock potential in a subterranean region of a hydrocarbon reservoir. One method includes receiving, an electron spin resonance (ESR) image from an in-situ ESR scanner that is attached to a wellbore at a first subterranean location, wherein the wellbore extends into the subterranean region of the hydrocarbon reservoir; determining, a spin concentration level of a source rock in the first subterranean location based on the ESR image; and determining, the source rock potential at the first subterranean location based on the determined spin concentration level.

Abstract: A downhole system includes a quartz enhanced photoacoustic spectrometer (QEPAS) configured to be positioned within a wellbore formed in a subterranean zone of a hydrocarbon formation, a sampling system coupled to the QEPAS, and a computer system connected to the QEPAS. The sampling system is configured to be positioned in the wellbore and obtain a sample of a wellbore fluid at a downhole location in the subterranean zone. The QEPAS is configured to spectroscopically scan the sample and to determine a plurality of quantities of a corresponding plurality of hydrocarbons in the same. The computer system includes one or more processors to perform operations including receiving the plurality of quantities of the plurality of hydrocarbons in the sample and determining a plurality of ratios, where each ratio is a ratio of one of the plurality of hydrocarbons with another of the plurality of hydrocarbons.

Abstract: The present disclosure describes methods and systems for determining source rock potential in a subterranean region of a hydrocarbon reservoir. One method includes receiving, an electron spin resonance (ESR) image from an in-situ ESR scanner that is attached to a wellbore at a first subterranean location, wherein the wellbore extends into the subterranean region of the hydrocarbon reservoir; determining, a spin concentration level of a source rock in the first subterranean location based on the ESR image; and determining, the source rock potential at the first subterranean location based on the determined spin concentration level.

Abstract: The present disclosure describes methods and systems for determining source rock potential in a subterranean region of a hydrocarbon reservoir. One method includes receiving, an electron spin resonance (ESR) image from an in-situ ESR scanner that is attached to a wellbore at a first subterranean location, wherein the wellbore extends into the subterranean region of the hydrocarbon reservoir; determining, a spin concentration level of a source rock in the first subterranean location based on the ESR image; and determining, the source rock potential at the first subterranean location based on the determined spin concentration level.

Abstract: The present disclosure describes methods and systems for determining source rock potential in a subterranean region of a hydrocarbon reservoir. One method includes: receiving, a terahertz (THz) scanning image from an in-situ THz scanner that is attached to a wellbore at a first subterranean location, wherein the wellbore extends into the subterranean region of the hydrocarbon reservoir; identifying, components of a source rock in the first subterranean location based on the THz scanning image; and determining, the source rock potential at the first subterranean location based on the identified components of the source rock.

Abstract: Embodiments of the invention provide an untethered apparatus for measuring properties along a subterranean well. According to at least one embodiment, the untethered apparatus includes a housing, and one or more sensors configured to measure data along the subterranean well. The data includes one or more physical, chemical, geological or structural properties in the subterranean well. The untethered apparatus further includes a processor configured to control the one or more sensors measuring the data and to store the measured data, and a transmitter configured to transmit the measured data to a receiver arranged external to the subterranean well. Further, the untethered apparatus includes a controller configured to control the buoyancy or the drag of the untethered apparatus to control a position of the untethered apparatus in the subterranean well. The processor includes instructions defining measurement parameters for the one or more sensors of the untethered apparatus within the subterranean well.

Abstract: An apparatus for determining properties of an uncharacterized downhole fluid. The apparatus comprises an oscillation driver circuit comprising an amplifier having an output and an input, a feedback loop between the output and input of an amplifier or a logic gate, an electromechanical resonator disposed within the feedback loop such that a the resonator is driven by the oscillation driver circuit, wherein a resonant frequency of the resonator defines an oscillation frequency of the oscillator circuit, and a switch device for causing the oscillator circuit to stop driving the resonator, which thereby enables observation of a decay rate of the oscillation of the electromechanical resonator within the uncharacterized fluid. The electromechanical resonator is enclosed in a conductive layer to protect the resonator against capacitive effects of the downhole fluid.

Abstract: A downhole system includes a quartz enhanced photoacoustic spectrometer (QEPAS) configured to be positioned within a wellbore formed in a subterranean zone of a hydrocarbon formation, a sampling system coupled to the QEPAS, and a computer system connected to the QEPAS. The sampling system is configured to be positioned in the wellbore and obtain a sample of a wellbore fluid at a downhole location in the subterranean zone. The QEPAS is configured to spectroscopically scan the sample and to determine a plurality of quantities of a corresponding plurality of hydrocarbons in the same. The computer system includes one or more processors to perform operations including receiving the plurality of quantities of the plurality of hydrocarbons in the sample and determining a plurality of ratios, where each ratio is a ratio of one of the plurality of hydrocarbons with another of the plurality of hydrocarbons.

Abstract: A method and device are described for making in situ measurements of the density and viscosity of downhole fluids at subterranean wells. An oscillator circuit is deployed in the well comprising an amplifier, a feedback loop, and an electromechanical resonator. The electromechanical resonator is a component in the feedback loop of the oscillator circuit, and has a resonance mode that determines the frequency of the oscillator circuit. The electromechanical resonator is also in contact with the fluid such that the density and viscosity of the fluid influence the resonant frequency and damping of the resonator. The frequency of the oscillator is measured by a microcontroller. In one embodiment, the oscillator circuit periodically stops driving the electromechanical resonator such that the oscillation decays and the rate of decay is also measured by the microcontroller. The density and viscosity of the fluid are determined from the frequency and rate of decay of the oscillation.

Abstract: The present disclosure describes methods and systems for determining source rock potential in a subterranean region of a hydrocarbon reservoir. One method includes receiving, an electron spin resonance (ESR) image from an in-situ ESR scanner that is attached to a wellbore at a first subterranean location, wherein the wellbore extends into the subterranean region of the hydrocarbon reservoir; determining, a spin concentration level of a source rock in the first subterranean location based on the ESR image; and determining, the source rock potential at the first subterranean location based on the determined spin concentration level.

Abstract: The present disclosure describes methods and systems for determining source rock potential in a subterranean region of a hydrocarbon reservoir. One method includes: receiving, a terahertz (THz) scanning image from an in-situ THz scanner that is attached to a wellbore at a first subterranean location, wherein the wellbore extends into the subterranean region of the hydrocarbon reservoir; identifying, components of a source rock in the first subterranean location based on the THz scanning image; and determining, the source rock potential at the first subterranean location based on the identified components of the source rock.