Abstract: A downhole monitoring system for continuously measuring in real-time a fluid produced from a reservoir includes a tubing extending into a wellbore, spaced apart packers forming annular seals between the tubing and a wall of the wellbore, isolated compartments formed between the spaced apart packers, each compartment having an opening in the tubing to allow fluid communication from the reservoir to surface equipment, and an ultraviolet spectrometer installed in each compartment. The ultraviolet spectrometer includes an ultra-violet source that excites diamondoids, a photomultiplier to quantify the excited diamondoids, and an electronic circuit that digitizes a response from the photomultiplier and sends the response to the surface of the wellbore. Additionally, a method includes continuously monitoring and in real-time a fluid produced from a reservoir and determining reservoir connectivity and reservoir profiling.

Abstract: Described is a device for measuring fluid density. The device is a flow meter including a housing with one side configured to mount to a flow conduit and define an outlet flow orifice near one end of the housing. The other side defines an inlet flow orifice near another end of the housing. The housing permits fluid to be introduced into the inlet flow orifice, flow through a flow cavity, and pass from the outlet flow orifice. The flow meter also includes a sensor head near the outlet flow orifice. The sensor head vibrates at a frequency upon introduction of electrical power while in contact with a fluid, detects the vibration frequency of the sensor head, and transmits the detected vibration frequency, which is associated with a density of the fluid. A system and method for determining a fluid density of a fluid using the described device is also disclosed.

Abstract: A downhole monitoring system for continuously measuring in real-time a fluid produced from a reservoir includes a tubing extending into a wellbore, spaced apart packers forming annular seals between the tubing and a wall of the wellbore, isolated compartments formed between the spaced apart packers, each compartment having an opening in the tubing to allow fluid communication from the reservoir to surface equipment, and an ultraviolet spectrometer installed in each compartment. The ultraviolet spectrometer includes an ultra-violet source that excites diamondoids, a photomultiplier to quantify the excited diamondoids, and an electronic circuit that digitizes a response from the photomultiplier and sends the response to the surface of the wellbore. Additionally, a method includes continuously monitoring and in real-time a fluid produced from a reservoir and determining reservoir connectivity and reservoir profiling.

Abstract: A method includes assembling a liner system by disposing a fiber optic cable circumferentially around an inner tube liner and locating an outer tube liner around the inner tube liner. The fiber optic cable is located between the inner tube liner and the outer tube liner. The method also includes spooling out the liner system, in a lay-flat state, into a conduit of a tubular structure positioned in the well, terminating spooling out the liner system when a select length of the liner system has been deployed in the conduit of the tubular structure, and securing the select length of the liner system deployed into the tubular structure at a surface above the well.

Abstract: Systems and components thereof are provided for analyzing multiphase production fluids. The system comprises a fluidic separation chamber, a fluidic separation chamber valve, fluidic piping configured to supply multiphase production fluid to the fluidic separation chamber through the fluidic separation chamber valve, a plurality of composite sensing modules vertically spaced within the fluidic separation chamber, and a fluidic supply and analysis unit. Each of the sensing modules comprising an inductive sensor comprising opposing inductive sensing elements displaced from one another across a vertically extending measurement portion of the fluidic separation chamber, and a capacitive sensor comprising opposing capacitive sensing elements displaced from one another across the vertically extending measurement portion of the fluidic separation chamber.

Abstract: A downhole fluid analysis system includes an optical sensor comprising, which includes a light source configured to emit light comprising a plurality of wavelengths, a light detector, and an optical tip through which at least a portion of the light travels and returns to the detector, wherein the incident angle of the light causes total internal reflection within the optical tip. The system further includes a piezoelectric helm resonator that generates a resonance response in response to an applied current, and an electromagnetic spectroscopy sensor positioned symmetrically with respect to the piezoelectric helm resonator in at least one direction. The light may be reflected in the optical tip at one or more reflection points, and each reflection point may generate an evanescent wave in a medium surrounding the optical tip. The light may be internally reflected in the optical tip at a plurality of reflection points.

Abstract: Described is a device for measuring fluid density. The device is a flow meter including a housing with one side configured to mount to a flow conduit and define an outlet flow orifice near one end of the housing. The other side defines an inlet flow orifice near another end of the housing. The housing permits fluid to be introduced into the inlet flow orifice, flow through a flow cavity, and pass from the outlet flow orifice. The flow meter also includes a sensor head near the outlet flow orifice. The sensor head vibrates at a frequency upon introduction of electrical power while in contact with a fluid, detects the vibration frequency of the sensor head, and transmits the detected vibration frequency, which is associated with a density of the fluid. A system and method for determining a fluid density of a fluid using the described device is also disclosed.

Abstract: Tools, processes, and systems for in-situ fluid characterization based on a thermal response of a fluid are provided. The thermal response of a downhole fluid may be measured using a downhole thermal response tool and compared with thermal responses associated with known fluids. The properties of the downhole fluid, such as heat capacity, diffusivity, and thermal conductivity, may be determined by matching the thermal response of the downhole fluid with a thermal response of a known fluid and using the properties associated with the known fluid. The composition of the downhole fluid may be determined by matching the viscosity of the downhole fluid to the viscosity of known fluid. A downhole thermal response tool for cased wellbores or wellbore sections and a downhole thermal response tool for openhole wellbores or wellbore sections are provided.

Abstract: A downhole fluid analysis system includes an optical sensor comprising, which includes a light source configured to emit light comprising a plurality of wavelengths, a light detector, and an optical tip through which at least a portion of the light travels and returns to the detector, wherein the incident angle of the light causes total internal reflection within the optical tip. The system further includes a piezoelectric helm resonator that generates a resonance response in response to an applied current, and an electromagnetic spectroscopy sensor positioned symmetrically with respect to the piezoelectric helm resonator in at least one direction. The light may be reflected in the optical tip at one or more reflection points, and each reflection point may generate an evanescent wave in a medium surrounding the optical tip. The light may be internally reflected in the optical tip at a plurality of reflection points.

Abstract: A method includes wrapping a packer bag around a deployment tool, providing at least one canister in fluid communication with the packer bag, sending the packer bag around the downhole tool to a downhole location in a well, and injecting a polymer filler material from the at least one canister into the packer bag until the packer bag expands to seal the downhole location.

Abstract: A multiphase flow metering device may have a conduit through which a multiphase fluid can flow and a structured packing insert positioned in the conduit. The structured packing insert may have a water-wet packing structure zone and/or an oil-wet packing structure zone. The multiphase flow metering device may also have a Halbach pre-polarizing magnet array positioned around the conduit, an RF coil, an electromagnet, an NMR console adapted to detect NMR signals from the multiphase fluid, and a control system configured to vary a polarization of the Halbach pre-polarizing magnet array. The Halbach pre-polarizing magnet array may be positioned or positionable over one or both of the oil-wet and water-wet packing structure zones. In some embodiments, the structured packing insert may include immobilized radicals, providing for dynamic nuclear polarization of the multiphase fluid.

Abstract: Techniques for measuring fluid properties include circulating a mixed-phase fluid flow through a fluid flow circuit; circulating the mixed-phase fluid flow through a pre-polarizing magnet; polarizing at least a gas phase of the mixed-phase fluid flow to an initial polarization; measuring fluid induction decay (FID) values of the polarized gas phase with the EFNMR detector; determining a velocity of the gas phase based on the FID values of the polarized gas phase; producing a pulsed magnetic field gradient to suppress one or more signals acquired by the EFNMR detector with a first electromagnet; measuring FID values of the liquid phase of the mixed-phase fluid with the EFNMR detector simultaneously with the production of the pulsed magnetic field gradient; producing a homogeneous polarizing field to polarize the liquid phase of the mixed-phase fluid with a second electromagnet; and determining a velocity and content of the liquid phase based on the FID values of the polarized liquid phase.

Abstract: A multiphase flow metering device may have a conduit through which a multiphase fluid can flow and a structured packing insert positioned in the conduit. The structured packing insert may have a water-wet packing structure zone and/or an oil-wet packing structure zone. The multiphase flow metering device may also have a Halbach pre-polarizing magnet array positioned around the conduit, an RF coil, an electromagnet, an NMR console adapted to detect NMR signals from the multiphase fluid, and a control system configured to vary a polarization of the Halbach pre-polarizing magnet array. The Halbach pre-polarizing magnet array may be positioned or positionable over one or both of the oil-wet and water-wet packing structure zones. In some embodiments, the structured packing insert may include immobilized radicals, providing for dynamic nuclear polarization of the multiphase fluid.

Abstract: A vortex flow meter is within a flow conduit. The vortex flow meter includes a housing defining a flow passage substantially in-line with the flow conduit. An actuable buff body is within the flow passage. A sensor is downstream of the actuable buff body and is attached to the housing. The sensor is configured to detect vortex shedding. A controller is configured to send a drive signal to an oscillator to oscillate the buff body. The controller is configured to receive a vortex stream from the sensor. The vortex stream is indicative of vortexes shed by the buff body within a fluid. The controller is configured to determine a flow velocity responsive to the received vortex stream.

Abstract: Methods, systems, and apparatus, including computer programs encoded on a computer storage medium, for monitoring slug flow in subterranean wells. In one aspect, a method includes at a time instant, transmitting an acoustic signal across a cross-section of a pipeline flowing multiphase fluid including gaseous fluid and liquid fluid, wherein a portion of the acoustic signal is carried through the cross-section of the pipeline by the multiphase fluid and determining, at the time instant, a first quantity of the gaseous fluid and a second quantity of the liquid fluid passing the cross-section of the pipeline based, in part, on an energy of the portion of the acoustic signal carried through the cross-section and at least a portion of a total energy of the transmitted acoustic signal.

Abstract: A downhole monitoring system for continuously measuring in real-time a fluid produced from a reservoir includes a tubing extending into a wellbore, spaced apart packers forming annular seals between the tubing and a wall of the wellbore, isolated compartments formed between the spaced apart packers, each compartment having an opening in the tubing to allow fluid communication from the reservoir to surface equipment, and an ultraviolet spectrometer installed in each compartment. The ultraviolet spectrometer includes an ultra-violet source that excites diamondoids, a photomultiplier to quantify the excited diamondoids, and an electronic circuit that digitizes a response from the photomultiplier and sends the response to the surface of the wellbore. Additionally, a method includes continuously monitoring and in real-time a fluid produced from a reservoir and determining reservoir connectivity and reservoir profiling.

Abstract: Techniques for measuring liquid properties include circulating a mixed oil-water liquid flow through a fluid flow circuit; polarizing the mixed oil-water liquid flow with a pre-polarizing magnet to an initial polarization; circulating the polarized mixed oil-water liquid flow to an EFNMR detector that includes a radio-frequency (RF) coil and a surrounding electromagnet; further polarizing the polarized mixed oil-water liquid flow with the surrounding electromagnet; measuring fluid induction decay (FID) values of the additionally polarized mixed oil-water liquid flow with the EFNMR detector; transforming the measured FID values to an effective adiabatic transition from the Earth's field to the polarizing field; determining a velocity of the oil in the mixed oil-water liquid flow and a velocity of the water in the mixed oil-water liquid flow based on differences in NMR signal relaxation properties of the transformed FID values; and determining an oil content and a water content of the mixed oil-water liquid flo

Abstract: Methods, apparatus and systems for in-situ heating fluids with electromagnetic radiation are provided. An example tool includes a housing operable to receive a fluid flowed through a flow line and a heater positioned within the housing. The heater includes a number of tubular members configured to receive portions of the fluid and an electromagnetic heating assembly positioned around the tubular members and configured to generate electromagnetic radiation transmitted to heat the tubular members. The heated tubular members can heat the portions of the fluid to break emulsion in the fluid. Upstream the heater, the tool can include a homogenizer operable to mix the fluid to obtain a homogenous fluid and a stabilizer operable to stabilize the fluid to obtain a linear flow. Downstream the heater, the tool can include a separator operable to separate lighter components from heavier components in the fluid after the emulsion breakage.

Abstract: Some examples of a method for manufacturing an electrode material for electrolytic hydrogen generation are described. Tungsten salt and nickel salt are mixed in a determined molar ratio on a carbon support by effectively controlling synthesis temperature and composition. Water and adsorbed oxygen, produced by mixing the tungsten salt and nickel salt are removed. Then, methane gas is flowed over the mixture resulting in the electrode material. The electrode material is suitable for use as a catalyst in electrolytic hydrogen generation processes, for example, at an industrial scale, to produce large quantities of hydrogen.

Abstract: An example system includes a moveable platform having an uphole end and a downhole end. The platform includes a drive arrangement for moving the platform in one or more directions along an interior wall of a casing string in a wellbore. The platform includes scraping arrangement for removing debris from the interior wall of the casing string. The platform includes a debris catching arrangement downhole of the scraping arrangement for collecting some or all of the debris removed. The platform may include a coating arrangement to deliver and apply a substance to at least a part of the wall of the casing string. The coating arrangement may include a reservoir holding one or more liquid substances and a valve to regulate flow of the one or more liquid substances. The liquid substance may include epoxy resin.