Abstract: Insulating fluids for use in drilling, production, and other applications are provided, the insulating fluids containing a porous medium (such as a sponge or foam) to limit the mobility of the liquid phase of the insulating fluid. The porous medium in the insulating fluid provides a mechanical means for reducing convective heat transfer, as the small pore spaces within the porous media create tortuous paths for the liquid moving therethrough. Methods include introducing the insulating fluid into an annulus of a drilling, riser, production, packer, or pipeline assembly to reduce heat transfer therethrough.

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: Systems and methods for this disclosure describe systems and methods that are directed to monitoring active clay in water-based drilling fluid may be provided. A method for monitoring active clay concentration while drilling may be provided. The method may include providing a sample of water-based drilling fluid. The method may further include adding methylene blue to the sample in a methylene blue titration. The method may further include performing an impedance measurement on the sample during the methylene blue titration. The method may further include determining an endpoint of the methylene blue titration using a phase angle measurement from the impedance measurement. The method may further include correlating the endpoint to the active clay concentration of the sample. The method may further include determining a treatment for the water-based drilling fluid based on the active clay concentration.

Abstract: The disclosure provides a method for determining a composition of a fluid. The method comprises diverting a sample of a portion of the fluid to a test chamber. The method further comprises actuating a heat source disposed around the test chamber to increase the temperature within the test chamber to produce vapors from the sample of the portion of the fluid and directing the vapors from the sample of the portion of the fluid to a chemical sensor array comprising one or more chemical sensors. The method further comprises determining a composition of the vapors from the sample of portion of the fluid, wherein the composition of the vapors is associated with the composition of the fluid.

Abstract: The disclosure presents processes for updating a prediction for the basin model and compaction model for a borehole. The results of the predicted parameters can be utilized by a drilling controller to adjust a drilling process, such as rotational speed, drilling fluid composition, drilling fluid additives, and other drilling process parameters. The predictions can be updated at various time intervals, such as real-time or near real-time for data collected by downhole sensors and a different time interval for sensor data collected at a lag time, such as cuttings analyzed by surface sensors. Throughout a drilling stage, the drilling process can be updated as new sensor data is received, allowing the uncertainty of the predictions to be reduced as new data is incorporated into the basin and compaction models, thereby enabling an increase in efficiency and optimization of the drilling process.

Abstract: Systems and methods of the present disclosure relate to optimizing a tripping velocity profile for pipes in a wellbore. A method for optimizing a tripping velocity profile for a pipe, comprising: determining a static gel strength of a fluid of a wellbore; determining an acceleration curve for the pipe in the wellbore based on wellbore pressure constraints, wherein the wellbore pressure constraints are based in part on the static gel strength of the fluid; determining a deceleration curve for the pipe; and combining the acceleration curve with the deceleration curve to provide the tripping velocity profile for the pipe.

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: The present disclosure relates to a pulsed-power drilling system that includes downhole mixers for restoring optimal electrical properties in drilling fluid. The downhole mixer may include a housing having an uphole and downhole end, a channel to convey the drilling fluid through the housing, and a flow restrictor including an orifice having a fixed diameter positioned in the channel between the entrance and the exit of the channel to create a pressure drop between the entrance and the exit of the channel during a drilling operation. The pressure drop increases shear stress in the drilling fluid to manage electrical properties, such as a dielectric constant, of the drilling fluid. The electrical properties of the drilling fluid facilitate the formation of an electrical arc on a drill bit of the pulsed-power drilling system.

Abstract: Certain aspects and features relate to a system and a sensor that provides real-time, downhole cutting concentration measurements. Electrical impedance measurements can be used in conjunction with a wired drill pipe to monitor the drill cuttings in the annulus under downhole conditions and along the drill string. This measurement provides direct information for optimal cuttings cleaning efficiency. In some examples, the system includes the sensor, a processing device connected to the sensor, and a non-transitory memory device including instructions that are executable by the processing device to cause the processing device to apply a transmitted signal to the sensor, receive an impedance signal from the sensor, and correlate the impedance signal with a wellbore cuttings concentration. In some examples the sensor includes multiple electrodes attachable to a drill string.

Abstract: A method comprises flowing a mud into a wellbore, wherein the mud has a mud composition and has a weight in a defined range. The method includes introducing a fluid pill into the mud flowing into the wellbore, wherein the fluid pill has an injection fluid with an injection composition that is different from the mud composition. A particulate has been added to the injection fluid to increase the weight of the fluid pill to be in the defined range. After flowing the mud into the wellbore such that the fluid pill is positioned in a zone of the wellbore: filtering out the particulate from the injection fluid; injecting, after the filtering, the injection fluid into the zone; measuring a downhole parameter that changes in response to injecting the injection fluid into the zone; and determining a property of the formation of the zone based on the measured downhole parameter.

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: Techniques of the present disclosure relate to downhole perforation operations using fluid containing hollow spheres. A method comprising: disposing a perforating apparatus in a volume of hollow particles in a wellbore; and detonating the perforating apparatus to collapse a portion of the hollow particles to increase flow through at least one perforation resulting from a detonation.

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: Systems and methods of the present disclosure relate to optimizing a tripping velocity profile for pipes in a wellbore. A method for optimizing a tripping velocity profile for a pipe, comprising: determining a static gel strength of a fluid of a wellbore; determining an acceleration curve for the pipe in the wellbore based on wellbore pressure constraints, wherein the wellbore pressure constraints are based in part on the static gel strength of the fluid; determining a deceleration curve for the pipe; and combining the acceleration curve with the deceleration curve to provide the tripping velocity profile for the pipe.

Abstract: Systems and methods for separating paramagnetic material in wellbore return fluid. A quadrupole magnet system is disposed along conduit so that a paramagnetic field is symmetrically formed about a central axis of the conduit. A wellbore return fluid containing paramagnetic material is directed through the conduit. The paramagnetic field drives the paramagnetic material outward towards the perimeter of the conduit, thereby concentrating fluid with little or no paramagnetic material along the central axis of the conduit. An outlet is disposed along the flow path of a portion of the concentrated fluid. In some embodiments, the outlet is positioned along the central axis, while in other embodiments, the outlet is positioned along the conduit wall. The paramagnetic material may be weighting material used to prepare drilling mud.

Abstract: Systems and methods to determine a characteristic of a drilling fluid are presented. A method to determine a characteristic of a drilling fluid includes obtaining a measurement of a mud density of a drilling fluid formed from a mixture of a plurality of components. The method also includes obtaining a measurement of a thermal conductivity of the drilling fluid and determining an error function of a calculation of characteristics of the drilling fluid, where the error function is indicative of a threshold difference between the calculation of the characteristics of the drilling fluid and the characteristics of the drilling fluid obtained from retort data of a fluid distillation process. The method further includes determining, based on the error function, an oil water ratio of the drilling fluid and an average specific gravity of the drilling fluid.

Abstract: A method including circulating wellbore servicing fluid (WSF) downhole, passing the circulating WSF through a separator configured to separate solids therefrom, separating the plurality of particles into screened particles having a diameter greater than or equal to a mesh size and retained particles having a diameter less than the mesh size in a particulate-reduced WSF, adding a volume of second loss circulation material (LCM) composition including replenishment particles to particulate-reduced WSF to provide LCM-adjusted WSF, and introducing LCM-adjusted WSF downhole and circulating LCM-adjusted WSF. The WSF includes first LCM composition including plurality of particles having first cumulative particle size distribution (PSD). The LCM-adjusted WSF includes LCM-adjusted WSF LCMs. LCM-adjusted WSF LCMs include the retained and replenishment particles.

Abstract: A method is disclosed comprising determining a concentration of one or more compounds of a fluid in an industrial water operation in real time. The determining of the concentration of the one or more components comprises contacting an array of sensors of a microelectromechanical system (MEMS) device with a sample of the fluid to provide a sample response indicative of the concentration of the one or more components. The method further provides adjusting or maintaining at least one operating parameter of the industrial water operation based on the concentration of the one or more components of the fluid.

Abstract: A method includes receiving a plurality of drilling parameters from a drilling operation, wherein the plurality of drilling parameters. The drilling parameters include a cuttings bed height and a friction factor between a drill string and a wellbore. The method further includes applying the plurality of drilling parameters to a friction model. The friction model utilizes a function of the cuttings bed height to determine a comprehensive friction factor. The comprehensive friction factor is applied to the plurality of drilling parameters to determine a required torque or hook load of the drill string. The method further includes providing an indication of a stuck pipe event.

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.