Abstract: Certain aspects and features of the present disclosure relate to real-time management of excessive torque, drag, and vibration along a drill string. In some aspects, torque, drag, vibration or any combination of these may be monitored at locations along the drill string, and these forces may be mitigated by adjusting the drilling fluid composition in real time. In some aspects, the forces may be mitigated by making real-time operational changes during wellbore drilling instead of or in addition to drilling fluid treatments.

Abstract: A system or method for monitoring drilling fluid. The system may comprise a fluid supply, wherein the fluid supply houses a drilling fluid, a pump, wherein the pump is fluidly connected to the fluid supply, a dispensation unit, wherein the dispensation unit is fluidly connected to the pump, and a process vessel, wherein the process vessel is fluidly coupled to the dispensation unit. The dispensation unit may comprise a housing, wherein the housing may comprise an internal cavity, an inlet, and an outlet. The dispensation unit may further comprise a top plate, wherein the top plate is configured to form a seal over the housing, and a diaphragm, wherein the diaphragm is disposed between the top plate and the housing. A method may comprise pumping the drilling fluid through a dispensation unit, actuating the dispensation unit, and determining a property of the drilling fluid.

Abstract: Effective prediction of downhole mixing and channeling at an interface between two or more wellbore fluids may prevent the unnecessary consumption of resources at a well site and enhance the performance of wellbore operations, including drilling operations, completion operations, and reservoir management. A model for a length and a volume of the interface between two wellbore fluids may be used to characterize the amount of mixing and channeling. The model may use known properties of the wellbore fluids before mixing and channeling occurs. The model may account for eccentricity in an annulus of the wellbore by partitioning a three dimensional flow profile in the wellbore into a plurality of segments for separate analysis. Outputs from the model may be used to determine one or more locations of the interface at one or more intervals of time as the wellbore fluids circulate through the wellbore.

Abstract: A method comprising determining a concentration of one or more components of a wellbore servicing fluid during a wellbore servicing operation; and adjusting or maintaining a composition of the wellbore servicing fluid being introduced into a wellbore and/or an operational parameter of the wellbore servicing operation based on the determining of the concentration of the one or more components, wherein the determining of the concentration of the one or more components comprises contacting a sample of the wellbore servicing fluid with a microelectromechanical system (MEMS) device to provide a sample response indicative of the concentration of the one or more components.

Abstract: Wall sealing and penetrator apparatus for use in penetrating walls in dangerous conditions. An example wall sealing and penetrator apparatus includes a first portion comprising: a first housing, a first sealing element, a first vacuum port; and a second portion comprising, a second housing, a second sealing element, a second vacuum port, and a cutting element.

Abstract: Systems and methods for adjusting well operations utilize measured values and curve fitting to determine predicted values of the gel strength of well-treatment fluids. The systems and methods are exemplified by first measuring a plurality of measured values representative of the gel strength of the well-treatment fluid, then determining a mathematical function that fits the plurality of measured values. From the mathematical function, the projected values are determined. The projected values are representative of the gel strength for the well-treatment fluid after a projected-value static period.

Abstract: Apparatuses and methods measure a specified volume of a drilling fluid for a test sample. An electrical parameter of the test sample is measured; and a chemical formulated to effect a change in the electrical parameter of the test sample is added in known increments. After each incremental addition of the chemical, the electrical parameter of the test sample is measured to determine if the electrical parameter measurement is at a stable value. When the electrical parameter measurement is at a stable value, the electrical parameter is correlated with an amount of water in the drilling fluid.

Abstract: Methods for the use of treatment fluids that include thermally responsive anti-sag agents in subterranean formations are provided. In one embodiment, the methods include introducing a treatment fluid including a base fluid and an anti-sag agent including a thermally responsive hydrogel that includes at least one thermoresponsive polymer into at least a portion of a subterranean formation.

Abstract: Methods for breaking polymer-containing treatment fluids for use in subterranean formations are provided. In one or more embodiments, the methods include providing a treatment fluid comprising a base fluid and a polymer, wherein the treatment fluid was recovered from at least a portion of a subterranean formation located at a wellsite; transporting the treatment fluid from the wellsite to an off-site location; and applying a cavitation technique to at least a portion of the treatment fluid at the off-site location.

Abstract: A method comprising determining a concentration of one or more components of a wellbore servicing fluid during a wellbore servicing operation; and adjusting or maintaining a composition of the wellbore servicing fluid being introduced into a wellbore and/or an operational parameter of the wellbore servicing operation based on the determining of the concentration of the one or more components, wherein the determining of the concentration of the one or more components comprises contacting a sample of the wellbore servicing fluid with a microelectromechanical system (MEMS) device to provide a sample response indicative of the concentration of the one or more components.

Abstract: A method includes determining a concentration of one or more components of a subterranean fluid, and adjusting or maintaining at least one operating parameter of a wellbore servicing operation based on the determining of the concentration of the one or more components. The subterranean fluid includes a fluid obtained from a subterranean formation during the wellbore servicing operation, and the determining of the concentration of the one or more components includes contacting a sample of the subterranean fluid with a microelectromechanical system (MEMS) device to provide a sample response indicative of the concentration of the one or more components.

Abstract: A rheometer apparatus and methods of use are provided. In one embodiment, the rheometer includes a sleeve having an interior space; a cylindrical bob disposed within the interior space of the sleeve and coupled to a first end of a bob shaft; a cross-spring pivot coupled to a second end of the bob shaft; an arm coupled to and projecting radially from the cylindrical bob; and a linear actuator coupled to the arm. In some embodiments, the rheometer apparatus may facilitate more accurate gel shear strength measurements and/or may be correlated with existing rheometer measurements.

Abstract: A corrective product addition treatment or surface treatment to a wellbore fluid is based on performing an artificial intelligence technique and/or a closed form solution with respect to one or more fluid properties. Pilot testing and operational testing to operatively dose a fluid at a drilling site may be integrated into the corrective product addition treatment or surface treatment to a wellbore fluid.

Abstract: An abrasive composition comprising a substrate selected from the group consisting of a fibrous substrate, a sponge substrate, and combinations thereof and a plurality of calcium carbonate particles dispersed therein; wherein at least a portion of the plurality of calcium carbonate particles contact the substrate; wherein the fibrous substrate comprises a plurality of fibers; wherein each fiber of the plurality of fibers is characterized by an aspect ratio of equal to or greater than about 2:1; wherein the sponge substrate is characterized by a porosity of equal to or greater than about 5 vol. %, based on the total volume of the sponge substrate; and wherein the abrasive composition is characterized by an abrasiveness that is greater than the abrasiveness of the substrate in the absence of the plurality of calcium carbonate particles.

Abstract: Systems and methods of the disclosed embodiments include a rheometer having a housing with a fluid inlet and a fluid outlet, a cylinder with a cavity located to receive fluid that passes into the fluid inlet, a motor configured to rotate the cylinder, a torsion bob within the cavity, and a controller located remotely from the rheometer. The controller includes a pressure regulator configured to pressurize fluid to power the motor, a rotation sensor configured to receive an optical rotation signal indicating a rotation speed of the cylinder, and a torque sensor configured to receive an optical signal indicating a torque on the torsion bob. The controller may be configured to receive a rotation speed signal from the rotation sensor, a torque signal from the torque sensor, and to calculate a shear stress for the fluid based on the rotation speed signal and the torque signal.

Abstract: This disclosure provides a method of determining a pore throat size distribution of reservoir rock, comprising injecting a set of different-sized probe particles through a portion of reservoir rock and measuring retention volumes or times of each of the different-sized probe particles eluting from the portion of reservoir rock. This disclosure also provides a testing apparatus comprising a probe tube for receiving a set of different-sized probe particles in an elution fluid returning from a portion of reservoir rock and an analytical module connected to receive the elution fluid from the probe tube.

Abstract: Apparatuses and methods measure a specified volume of a drilling fluid for a test sample. An electrical parameter of the test sample is measured; and a chemical formulated to effect a change in the electrical parameter of the test sample is added in known increments. After each incremental addition of the chemical, the electrical parameter of the test sample is measured to determine if the electrical parameter measurement is at a stable value. When the electrical parameter measurement is at a stable value, the electrical parameter is correlated with an amount of water in the drilling fluid.

Abstract: Systems and methods for adjusting well operations utilize measured values and curve fitting to determine predicted values of the gel strength of well-treatment fluids. The systems and methods are exemplified by first measuring a plurality of measured values representative of the gel strength of the well-treatment fluid, then determining a mathematical function that fits the plurality of measured values. From the mathematical function, the projected values are determined. The projected values are representative of the gel strength for the well-treatment fluid after a projected-value static period.

Abstract: A method comprising determining a concentration of one or more components of a wellbore servicing fluid during a wellbore servicing operation; and adjusting or maintaining a composition of the wellbore servicing fluid being introduced into a wellbore and/or an operational parameter of the wellbore servicing operation based on the determining of the concentration of the one or more components, wherein the determining of the concentration of the one or more components comprises contacting a sample of the wellbore servicing fluid with a microelectromechanical system (MEMS) device to provide a sample response indicative of the concentration of the one or more components.

Abstract: A method includes determining a concentration of one or more components of a subterranean fluid, and adjusting or maintaining at least one operating parameter of a wellbore servicing operation based on the determining of the concentration of the one or more components. The subterranean fluid includes a fluid obtained from a subterranean formation during the wellbore servicing operation, and the determining of the concentration of the one or more components includes contacting a sample of the subterranean fluid with a microelectromechanical system (MEMS) device to provide a sample response indicative of the concentration of the one or more components.