Abstract: An apparatus for testing lost circulation materials (“LCMs”) for use in a formation is disclosed. The apparatus may comprise a LCM cell that contains at least one formation simulation component. A pressurized tank may be in fluid communication with the LCM cell, and may force a sample LCM slurry into the LCM cell. An LCM receiver may also be in fluid communication with the LCM cell, and may receive the LCM slurry that flows through the LCM cell.

Abstract: The present disclosure describes various systems and methods for creating and presenting optimization visualizations that use normalized achievement variables. At least one illustrative method includes defining achievement functions that each operates on at least one of several achievement variables (each of the achievement variables representing a characteristic of a physical object or process), and transforming value ranges for at least two achievement variables into corresponding achievement level ranges by applying at least one of the achievement functions to the value ranges of the achievement variables (the achievement variables being a function of at least one common control variable). The method further includes combining the corresponding achievement level ranges to produce a combined achievement level range, and presenting a visual representation of the combined achievement level range to a user, enabling the user to select value ranges for the common control variable.

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: Turbidity measurement systems and methods of using the same are described. A turbidity measurement system comprise a vessel configured to hold a wellbore fluid, wherein a permeable obstruction to flow is positioned in the vessel; a light source positioned to direct light at the vessel; a light detector positioned to measure light intensity of light emitted by the light source and passing through the vessel; and a backscatter detector positioned to measure the light intensity of reflected light emitted from the light source.

Abstract: Turbidity measurement systems and methods of using the same are described. A turbidity measurement system comprises a vessel configured to hold a wellbore fluid, wherein a porous media is positioned in the vessel; a light source positioned to direct light at the vessel; a light detector positioned to measure light intensity of light emitted by the light source and passing through the vessel; a backscatter detector configured to measure the light intensity of reflected light emitted from the light source; and a computer system communicatively coupled to at least one of the light source, light detector, or light detector.

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.

Abstract: A treatment fluid comprises: a base fluid; a lost-circulation material, wherein the lost-circulation material inhibits or prevents some or all of the treatment fluid from penetrating into a subterranean formation from a wellbore, wherein the wellbore penetrates the subterranean formation; and a suspending agent, wherein the suspending agent consists of a plurality of fibers, and wherein the suspending agent provides a lost-circulation material distribution of at least 30% for a test treatment fluid consisting essentially of the base fluid, the lost-circulation material, and the suspending agent at the temperature of a lost-circulation zone of the subterranean formation and static aging for at least 1 hour.

Abstract: Methods and compositions for treating a subterranean formation are described. The methods include providing a petrified cellulosic material, combining the petrified cellulosic material with a treatment fluid, and introducing the treatment fluid with the petrified cellulosic material in the subterranean formation.

Abstract: Certain invert emulsion treatment fluids and methods for use in subterranean formations Certain of those methods herein include: 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: Methods including precipitated and mined calcium carbonate lost circulation materials for use in subterranean formation operations. The precipitated calcium carbonate lost circulation materials are formed under a chosen set of precipitation conditions, including in situ in a subterranean formation. The mined calcium carbonate lost circulation materials are obtained in a desired morphological form under naturally occurring mined conditions. The precipitated and mined calcium carbonate lost circulation materials may be needle-shaped aragonite having an aspect ratio of about 1.4 to about 15.

Abstract: Various embodiments disclosed relate to weighted compositions for treatment of a subterranean formation. In various embodiments, the present invention provides a method of treating a subterranean formation. The method can include placing in the subterranean formation a coated weighting agent. The coated weighting agent can include a weighting agent and an inorganic coating material on the weighting agent.

Abstract: A sag-resistant fluid, such as a drilling fluid, a completion fluid, or a spacer fluid, including a colloidal suspension that includes a continuous liquid phase and a solid phase suspended in the continuous liquid phase. The solid phase includes a plurality of particles, having an average diameter of the plurality of particles less than about 1000 nm. The sag-resistant fluid has a density of from about 7 to about 30 lbm/gal, and exhibits a density variation of less than about 0.5 lbm/gal over a time period of at least about 16 hours. A method including circulating the sag-resistant fluid through a well.

Abstract: A cognitive computing system for producing chemical formulations, in some embodiments, comprises: neurosynaptic processing logic; and one or more information repositories accessible to the neurosynaptic processing logic, said one or more repositories storing resources, wherein the neurosynaptic processing logic determines a first chemical formulation to achieve a target and to satisfy one or more constraints, produces and tests said first chemical formulation, and analyzes the results of the test using said resources to determine a second chemical formulation, wherein the second chemical formulation more closely achieves the target and satisfies the one or more constraints than the first chemical formulation.

Abstract: A cognitive computing system for enhancing drilling operations, in some embodiments, comprises: neurosynaptic processing logic; and one or more information repositories accessible s to the neurosynaptic processing logic, wherein the neurosynaptic processing logic performs a probabilistic analysis of one or more real-time drilling operations measurements, one or more resources obtained from said one or more information repositories, and one or more drilling operations simulations that account for said one or more real-time drilling operations measurements, wherein the neurosynaptic processing logic controls a drilling operation based at least in part on said probabilistic analysis.

Abstract: Disclosed are methods in which measurements are obtained from a plurality of sensors secured in spaced relation to one another across at least a portion of the depth of reservoir of some form in order to identify one or more characteristics of the fluids within the reservoir. The sensors are used to monitor ambient forces exerted by fluids within the tank proximate each sensor. An example mechanism for obtaining the measurements includes a plurality of sensors, such as strain gauges, supported on a structure that supports the sensors in fixed relation to one another, and can, in some examples, support the sensors in a known relation relative to boundaries of the reservoir.

Abstract: Apparatus and methods for simulation of bore hole fractures are disclosed. A device for simulating a fracture in a subterranean formation comprises a housing, a gap in the housing, and one or more shims positioned inside the gap. The shims cover at least a portion of a surface of a wall forming the gap. The device further comprises an inlet for directing a sample fluid into the gap. The sample fluid flows through the gap and flows out of the gap through an outlet.

Abstract: Methods and apparatuses that measure thermal conductivity and electrical conductivity of a emulsified drilling fluid may be used to indirectly measure the salinity and the average specific gravity of the solids in the emulsified drilling fluid. For example, a drilling assembly may comprise a drill string extending into a wellbore penetrating a subterranean formation; a pump configured to circulate a drilling fluid through the drilling assembly; a first flow line fluidly coupling the wellbore to a retention pit; a second flow line fluidly coupling the retention pit to the pump; a third flow line fluidly coupling the pump to the drill string; and an in-line analysis system fluidly coupled to the retention pit, fluidly coupled to the second flow line, or fluidly coupled to the third flow line, the in-line analysis system comprising a thermal conductivity meter and/or an electrical conductivity meter to a sample container.

Abstract: An apparatus including an electromagnetic radiation source that emits electromagnetic radiation, a sample chamber comprising a fluid sample inlet for introducing a solids-laden fluid sample therein, and a detector that receives a backscattering signal and generates an output signal corresponding to a concentration of solids in the solids-laden fluid sample. The electromagnetic radiation transmits through the sample chamber and optically interacts with the solids-laden fluid sample to generate a backscattering signal. The sample chamber may include one or more of a shear bob for applying a shear rate to the solids-laden fluid sample, the shear bob suspended in the sample chamber and rotatable about an axis, a sealable fluid pressurizing inlet for pressurizing the sample chamber and a pressure gauge for measuring the pressure in the sample chamber when pressurized, and/or a temperature source for heating the solids-laden fluid sample.

Abstract: The disclosure relates to an electrocrushing drilling fluid with an electrocrushing drilling base fluid including a non-polar oil, —OH, —(OH)2, or —(OH)3 alcohol, water, and an emulsifier in proportional amounts by weight or volume in that order. The electrocrushing drilling fluid may further contain at least one additive. The electrocrushing drilling fluid may have a dielectric constant or dielectric strength of at least a set amount, an electric conductivity or viscosity less than a set amount, or a combination of these properties. The disclosure further relates to an electrocrushing drilling system containing the electrocrushing drilling fluid and an electrocrushing drill bit and a method of electrocrushing drilling.

Abstract: Systems and methods for monitoring and characterizing well bores, subterranean formations, and/or fluids in a subterranean formation using well evaluation pills are provided. In one embodiment, the methods comprise: introducing a well evaluation pill into a portion of a well bore penetrating a portion of a subterranean formation; allowing the well evaluation pill to interact with one or more components in the portion of the subterranean formation; detecting a change in the composition or properties of the well evaluation pill; and determining the presence of one or more components in the portion of the subterranean formation based at least in part on the detected change in the composition or properties of the well evaluation pill.