Abstract: A yield stress measurement device and corresponding methods may use a two-capillary tube setup that measures the amount of a fluid drawn into each capillary and correlates that to the yield stress of the fluid. The devices and corresponding methods may be particularly useful for in-the-field measurements at well sites during drilling operations or other wellbore operations. An exemplary yield stress measurement apparatus may include a first capillary tube and a second capillary tube substantially perpendicular to each other, each capillary tube having two open ends and a length extending therebetween; a first and second length scale coupled to the lengths of the first and second capillary tubes, respectively; and a first fluid area and a second fluid area at one of the open ends of each of the first and second capillary tubes, respectively.

Abstract: A system for facilitating meetings, in some embodiments, comprises: neurosynaptic processing logic; and one or more information repositories accessible to the neurosynaptic processing logic, wherein, during a meeting of participants that includes the neurosynaptic processing logic, the neurosynaptic processing logic accesses resources from the one or more information repositories to perform a probabilistic analysis, and wherein, based on said probabilistic analysis, the neurosynaptic processing logic answers a question from one or more of the participants, asks a question of the participants, makes a statement to the participants, or provides a suggestion to the participants.

Abstract: A cognitive computing system for enhancing oilfield operations, in some embodiments, comprises: neurosynaptic processing logic; and one or more information repositories accessible to the neurosynaptic processing logic, wherein the neurosynaptic processing logic produces a recommendation in response to an oilfield operations indication, the neurosynaptic processing logic produces said recommendation based on a probabilistic analysis of said oilfield operations indication, resources in the one or more information repositories, and oilfield operations models in the one or more information repositories, said oilfield operations models pertaining to oilfield operations associated with said indication, wherein the neurosynaptic processing logic presents said recommendation to a user.

Abstract: Various embodiments include apparatus and methods to execute corrective product addition treatment or surface treatment to a wellbore fluid based on performing an artificial intelligence technique and/or a closed form 5 solution with respect to one or more fluid properties. Apparatus and methods can be implemented to integrate pilot testing and operational testing to operatively dose a fluid at a drilling site. Additional apparatus, systems, and methods are disclosed.

Abstract: Thermal conductivity measurements of a wellbore fluid may be used to derive the sag of the wellbore fluid (i.e., the inhomogeneity or gradation in particle distribution in the fluid as a result of the particles settling). For example, a method may include measuring a thermal conductivity of a fluid at two or more locations along a height of a vessel containing the fluid that comprises particles dispersed in a base fluid; and calculating a sag of the fluid based on the thermal conductivity at the two or more locations. In some instances, the temperature and pressure of the wellbore fluid may be changed and/or the wellbore fluid may be sheared to investigate their effects on sag.

Abstract: Mineral particles may provide for wellbore fluids with tailorable properties and capabilities, and methods relating thereto. Mineral particles may be utilized in methods that include introducing a wellbore fluid having a density of about 7 ppg to about 50 ppg into a wellbore penetrating a subterranean formation, the wellbore fluid comprising a base fluid and a plurality of mineral particles, and the wellbore fluid having a first viscosity; contacting at least some of the mineral particles with a linking agent so as to link the at least some of the mineral particles, thereby increasing the first viscosity to a second viscosity.

Abstract: Shear thinning fluids may be useful as calibration fluids for calibrating rheometers with bob/rotor eccentricity and at lower shear rates, which may be particularly useful for calibrating rheometers at well sites that are used for measuring the rheological properties of complex fluids (e.g., wellbore fluids like drilling fluids, cementing fluids, fracturing fluids, completion fluids, and workover fluids). Additionally, high shear rate calibrations may also be performed with shear thinning calibration fluids. Newtonian fluids may be used for high shear rate calibrations in alternate of or in addition to the shear thinning calibration fluid.

Abstract: A managed pressure drilling (MPD) operation may use an inverse model in conjunction with a hydraulic model and real-time drilling conditions and parameters as inputs to determine a wellhead pressure set point corresponding to a desired bottomhole pressure. For example, while drilling a wellbore penetrating a subterranean formation with a drilling system, measured data including a wellhead pressure may be acquired. A model may then be executed that applies a hydraulic model to an a priori model estimate vector to produce predicted data; converts the measured data to a measured data vector; applies a randomized maximum likelihood algorithm to the a priori model estimate vector, the predicted data, and the measured data vector to produce an a posterioiri model estimates; and applies the hydraulic model to the a posterioiri model estimates to produce an a posteriori prediction and a calculated wellhead pressure set point corresponding to a desired bottomhole pressure.

Abstract: A method for the determination of the oil content for solids recovered from a wellbore is provided. The method comprises providing the solids recovered from the wellbore and measuring the thermal conductivity of the solids recovered from the wellbore using a thermal conductivity probe. The method further comprises using the thermal conductivity measurement to determine the oil content in the solids recovered from the wellbore.

Abstract: Beneficiating particulate additives by removing contaminants or minerals that impact the quality and specific gravity of the particulate additives may be achieved via dry solids separation technologies. For example, an air classifier, an electrostatic separator, and a combination thereof may be used to produce a beneficiated particulate additive comprising less than 40% of drill solids by weight of the beneficiated particulate additive.

Abstract: A system and method for rheology measurements. The system may comprise a conduit; an ultrasound transmitter positioned to direct ultrasound pulses into the conduit; an ultrasound receiver positioned to receive sound waves from the conduit; a pump fluidically coupled to the conduit; and a heat exchanger fluidically coupled to the conduit. The method may comprise drawing a sample of a treatment fluid into the rheology measurement system; pressuring the sample of the treatment fluid; adjusting temperature of the treatment fluid; directing ultrasound pulses into the treatment fluid while the treatment fluid is flowing through the rheology measurement system; measuring sound waves reflected by the treatment fluid; and determining a velocity profile of the treatment fluid based at least on the measured sound waves.

Abstract: A method of managing bottom hole assembly vibrations while drilling a wellbore including obtaining data regarding drilling parameters related to one or more drilling operations, determining if the bottom hole assembly has vibration levels outside of the range of normal operation parameters, modifying the drilling mud formulation to alter at least one of its physical properties and rheological properties to keep or maintain the vibration levels of the bottom hole assembly within the range of normal operation parameters, and mitigating the vibrations.

Abstract: The present disclosure relates to systems and methods for wellbore pressure control with separated fluid columns. One embodiment is a composition comprising: a base fluid, a hectorite clay, a secondary clay comprising at least one clay selected from the group consisting of an attapulgite clay, a sepiolite clay, a polygorskite clay, and any combination thereof, and a plurality of fibers. Another embodiment is a method comprising: introducing a first fluid into a wellbore; introducing a barrier pill into the wellbore, wherein the barrier pill comprises: a base fluid, a hectorite clay, and a plurality of fibers; and introducing a second fluid into the wellbore.

Abstract: A system to facilitate communication, in some embodiments, comprises a controller, storage in communication with the controller and storing resources available to the controller, and a plurality of wearable devices in wireless communication with the controller and with each other. Each of the plurality of wearable devices receives input and provides the input to at least one of the controller or another one of the plurality of wearable devices. The controller performs an action based at least on the resources and the input.

Abstract: A cognitive computing system for enhancing workflow performance in the oil and gas industry, in some embodiments, comprises: neurosynaptic processing logic including multiple electronic neurons operating in parallel; input and output interfaces coupled to the neurosynaptic processing logic; and one or more information repositories accessible to the neurosynaptic processing logic, wherein the neurosynaptic processing logic receives a workflow enhancement request via the input interface, accesses the one or more information repositories to obtain information pertaining to the request, uses said information to perform a probability analysis, produces an option relating to the workflow enhancement request based on said probability analysis, and presents said option via the output interface.

Abstract: Embodiments herein include methods comprising providing a drill-in fluid comprising an aqueous base fluid and nanoparticulates; providing a drilling apparatus comprising a drill string and a drill bit; circulating the drill-in fluid while drilling a reservoir interval in a subterranean formation with the drilling apparatus such that the nanoparticles penetrate into the subterranean formation; and consolidating unconsolidated particles within the subterranean formation with the nanoparticles.

Abstract: A system and method for rheology measurement of a drilling fluid. The system may comprise an ultrasound transmitter positioned to direct ultrasound pulses into the drilling fluid; an ultrasound receiver positioned to receive sound waves reflected from the drilling fluid; and a computer system configured to determine a velocity profile of the drilling fluid based at least in part on the reflected sound waves. The method may comprise flowing at least a portion of the drilling fluid through a rheology measurement system; directing ultrasound pulses into the drilling fluid while the drilling fluid is flowing through the rheology measurement system; measuring sound waves reflected by the drilling fluid; and determining a velocity profile of the drilling fluid based at least on the measured sound waves.

Abstract: A system and method for measuring rheology of a treatment fluid. The system may comprise an ultrasound transmitter positioned to direct ultrasound pulses into the treatment fluid as the treatment fluid is being introduced into a wellbore; an ultrasound receiver positioned to receive sound waves reflected from the treatment fluid; and a computer system configured to determine a velocity profile of the treatment fluid based at least in part on the reflected sound waves. The method may comprise introducing a treatment fluid into a wellbore by way of a conduit; directing ultrasound pulses into the treatment fluid; measuring sound waves reflected by the treatment fluid; and determining a velocity profile of the treatment fluid based at least on the measured sound waves.

Abstract: Certain invert emulsion treatment fluids for use in subterranean formations are provided. In certain embodiments, the methods comprise: providing an invert emulsion treatment fluid that comprises an oleaginous external phase, and an internal phase that comprises one or more alcohols and one or more polar organic compounds that are soluble in the internal phase; and introducing the treatment fluid into at least a portion of a subterranean formation.

Abstract: A role-based information distribution system, in some embodiments, comprises a display to provide an image containing multiple dynamic icons. It further comprises a wearable device camera to capture the image, and processing logic, coupled to the camera, to interpret the multiple dynamic icons and to provide information pertaining to a selected one or more of the multiple dynamic icons to a user via the wearable device. The processing logic selects the selected one or more of the multiple dynamic icons based on a role associated with the user.