Abstract: Disclosed herein are methods and systems that use magnetic complexes in wellbore monitoring. A well monitoring system may comprise magnetic complexes disposed in a subterranean formation, wherein the magnetic complexes each comprise a first magnetic portion, a second magnetic portion, and a spacer portion; and an electromagnetic interrogator, wherein the electromagnetic interrogator comprises an electromagnetic source and an electromagnetic detector.

Abstract: A drilling operation can be optimized based on feedback provided by density sensors in a flow pipe. The drilling can be in a wellbore penetrating a subterranean formation while circulating a drilling fluid. The sensor can be used to detect an actual density of cuttings in the drilling fluid and within a region of the flow pipe. A modelled density of the cuttings can be calculated for the region based on an initial model. The initial model can be based on a comparison of an equivalent circulating density profile to a fracture gradient of the subterranean formation. Based on a comparison of the actual density of the cuttings to the modelled density of the cuttings, the initial model can be adjusted to generate an adjusted model. At least one operational parameter of the drilling can be changed based on the adjusted model.

Abstract: Determining a type of annular material in a wellbore comprises measuring an acoustic noise of one or more reference materials and thereby generating a corresponding one or more acoustic profiles, monitoring the annular material with an acoustic sensor positioned in the wellbore and thereby obtaining an acoustic response of the annular material, comparing the acoustic response with the one or more acoustic profiles using a processor communicably coupled to the acoustic sensor, and characterizing the annular material based on the comparison of the acoustic response and the one or more acoustic profiles.

Abstract: The present disclosure provides a method, computer system and computer program product for branch optimization. According to the method, execution possibilities of instruction blocks corresponding to at least one branch of in a program can be determined. Then, the instruction blocks can be loaded according to the execution possibilities.

Abstract: Fluid properties like viscosity, yield strength, and density may be measured by analyzing fluid motion in response to disturbing the surface of the fluid. For example, a method may include disturbing a surface of a fluid in one or more locations, thereby forming a deformation and waves at the surface of the fluid for the one or more locations; imaging and measuring at least one selected from the group consisting of the deformation, the waves, and a combination thereof; and calculating a property of the fluid based on the at least one selected from the group consisting of the deformation, the waves, and a combination thereof, the property selected from the group consisting of viscosity, yield strength, density, and any combination thereof.

Abstract: Systems and methods for determining the composition of a drilling fluid using electro-rheology may be provided. A method for drilling a wellbore may include: circulating a drilling fluid in a wellbore; extending the wellbore into one or more subterranean formations; measuring impedance of at least a portion of the drilling fluid over time as one or more particulate additives in the drilling fluid settle; determining one or more model elements of an equivalent circuit model for modeling frequency responses of the drilling fluid from the impedance; and determining sag behavior of the drilling fluid based, at least partially, on the one or more model elements.

Abstract: Systems and methods for measurement of the oil, water, and/or solids concentration in oil-based drilling fluids may be provided in accordance with embodiments of the present disclosure. An example method for monitoring oil-based drilling fluids may include providing a sample of an oil-based drilling. The method may further include determining an estimate of an oil concentration of the sample. The method may further include measuring thermal conductivity of the sample. The method may further include determining an estimate of solids concentration of the sample from a correlation that relates the oil concentration, the thermal conductivity, and the solids concentration.

Abstract: Systems and methods for measurement of the oil content in oil-based drilling may be provided in accordance with embodiments of the present disclosure. A method for measuring oil content of an oil-based drilling fluid may include providing a sample of the oil-based drilling fluid. The method may further include performing electro impedance spectroscopy on the sample by a process that comprises applying an alternating electric current to the sample and measuring a response of sample to obtain electro impedance spectroscopy measurements. The method may further include determining an estimate of the oil content of the sample based, at least partially on the electro impedance spectroscopy measurements.

Abstract: A frequency sensor comprises a surface functionalized with a reactant sensitive to an analyte and a vibration detector coupled to the functional surface to detect a frequency of a fluid having the analyte and located on the functional surface during vibration thereof. The frequency sensor comprises a measurement circuitry coupled to the vibration detector to determine a frequency shift over time of the detected frequency, wherein the frequency shift corresponds to the presence of the analyte which has reacted with the reactant.

Abstract: A method includes collecting tracer concentration measurements from a flow stream in a borehole as a function of time. The method also includes recovering an uplink telemetry signal from the collected tracer concentration measurements, wherein the uplink telemetry signal conveys a downhole tool measurement or communication. The method also includes performing an operation in response to the recovered uplink telemetry signal.

Abstract: The disclosed embodiments include downhole communication networks and methods to form downhole communication networks. In one embodiment, a downhole communication network includes a plurality of communication tags deployed in a wellbore. Each communication tag of the plurality of communication tags includes a sensor operable to detect wellbore and hydrocarbon resource properties proximate the respective communication tag. Each communication tag of the plurality of communication tags also includes a storage medium operable to store data indicative of the at least one of wellbore and hydrocarbon resource properties proximate the respective communication tag. Each communication tag of the plurality of communication tags further includes a transmitter operable to transmit a signal indicative of one or more of the wellbore and hydrocarbon resource properties.

Abstract: Optical fiber having a graphene coating, a method to apply a graphene coating onto an optical fiber, and a fiber optic cable having a graphene coating are disclosed. A first carbon based coating is applied to an optical fiber along a longitudinal axis of the optical fiber. A laser beam is focused at the first carbon based coating. A first surface of the first carbon based coating is photothermally converted into a first layer of graphene.

Abstract: An illustrative method for measuring a fluid viscosity that includes vibrating a tube containing a fluid of interest, obtaining a vibration signal from the vibrating tube, deriving a system energy loss rate measurement from the vibration signal, calculating an energy loss rate for the fluid of interest from the system energy loss rate measurement and a reference energy loss rate measurement, and generating a viscosity measurement of the fluid of interest based on the energy loss rate for the fluid of interest and a density of the fluid of interest.

Abstract: The disclosed embodiments include an optical fiber having a graphene coating, a method to apply a graphene coating onto an optical fiber, and a fiber optic cable having a graphene coating. In one embodiment, the optical fiber includes an optical core that extends along a longitudinal axis. The optical fiber also includes a carbon based coating that covers the optical core along the longitudinal axis. The optical fiber also includes a layer of graphene formed on a first surface of the carbon based coating. The layer of graphene is formed from a laser induction process that includes focusing a laser beam at the carbon based coating to photothermally convert the first surface of the carbon based coating into graphene.

Abstract: The disclosed embodiments include an optical fiber having a graphene coating, a method to apply a graphene coating onto an optical fiber, and a fiber optic cable having a graphene coating. In one embodiment, the optical fiber includes an optical core that extends along a longitudinal axis. The optical fiber also includes a carbon based coating that covers the optical core along the longitudinal axis. The optical fiber also includes a layer of graphene formed on a first surface of the carbon based coating. The layer of graphene is formed from a laser induction process that includes focusing a laser beam at the carbon based coating to photothermally convert the first surface of the carbon based coating into graphene.

Abstract: Systems and methods for determining the composition of a drilling fluid using electro-rheology.

Abstract: A valve body includes a mixing chamber within the valve body, a plurality of passages through the valve body into the mixing chamber, and a sensor located within the valve body. The sensor has a sensor output representing a property of a fluid within the valve body. A processor is coupled to the sensor output. The processor is programmed to use the sensor output, a density of oil and a density of a subject fluid to determine a fraction of the subject fluid in a fluid flowing through one of the plurality of passages.

Abstract: Disclosed are telemetry systems and methods that employ a plurality of electromagnetic transceivers disposed outside a well casing string at a corresponding plurality of depths along the casing string. Each transceiver includes one or more toroidal inductors circumferentially surrounding the casing string and inductively coupled thereto to allow signal transmission between transceivers via currents induced in the casing. In some embodiments, signals are relayed via a chain of transceivers to facilitate indirect communication between a surface facility and other transceivers located too deep for direct communication to the surface.

Abstract: A method includes collecting tracer concentration measurements from a flow stream in a borehole as a function of time. The method also includes recovering an uplink telemetry signal from the collected tracer concentration measurements, wherein the uplink telemetry signal conveys a downhole tool measurement or communication. The method also includes performing an operation in response to the recovered uplink telemetry signal.

Abstract: A production tubing carries fluids from a producing zone to a surface. A resonant tube densitometer measures the density of the fluids carried by the production tubing. The resonant tube densitometer has a tube. A longitudinal section of the production tubing is the tube of the resonant tube densitometer.