Abstract: A method for determining motional branch current in an ultrasonic transducer of an ultrasonic surgical device over multiple frequencies of a transducer drive signal. The method may comprise, at each of a plurality of frequencies of the transducer drive signal, oversampling a current and voltage of the transducer drive signal, receiving, by a processor, the current and voltage samples, and determining, by the processor, the motional branch current based on the current and voltage samples, a static capacitance of the ultrasonic transducer and the frequency of the transducer drive signal.

Abstract: Described herein are engineered nucleases comprising mutations in the cleavage domain (e.g., FokI or homologue thereof) and/or DNA binding domain (zinc finger protein, TALE, single guide RNA) such that on-target specificity is increased.

Abstract: Methods and systems are provided for an electric drive train of a vehicle. In one example, a four-node planetary gear set is included in the electric drive train with a first motor coupled to a first input node and a second motor coupled to a second input node of the four-node planetary gear set. The drive train may be operated at a first mechanical point when the first electric machine is operated at a substantially zero speed, and the drive train may be operated at a second mechanical point when the second electric machine is operated at a substantially zero speed, in one or more examples. Operation at either the first mechanical point or the second mechanical point may be achieved without clutches or hydro-mechanical devices.

Abstract: Provided herein are energy storage devices. In some cases, the energy storage devices are capable of being transported on a vehicle and storing a large amount of energy. An energy storage device is provided comprising at least one liquid metal electrode, an energy storage capacity of at least about 1 MWh and a response time less than or equal to about 100 milliseconds (ms).

Abstract: A system for interoperating and communicating data from a device having a communications gateway and at least one tactical device connected to an electrified rail providing electrical power. The system includes at least one processor, and at least one non-transitory computer-readable data storage device storing data instructions that, when executed by the at least one processor, cause the system to receive an event from the device, determine whether the event triggers a workflow, and execute an action on the device in response to the workflow being triggered.

Abstract: Disclosed herein are compositions for linking DNA binding domains and cleavage domains (or cleavage half-domains) to form non-naturally occurring nucleases with alternative configurations. Also described are methods of making and using compositions comprising these linkers.

Abstract: Invert emulsions can be used in oil and gas operations. A fluid loss control additive (FLCA) is a component of the fluid that can be utilized to control or minimize fluid loss into a subterranean formation. The FLCA can be a chemically modified vegetable oil that is biodegradable. Vegetable oils having some or all of the functional groups sulfonated can be used as FLCA. A water-soluble salt that has been dissolved in the discontinuous phase of the invert emulsion can combine with the FLCA to form a wax-like, solid mass.

Abstract: A treatment fluid can include a base fluid and a stabilizing additive. The stabilizing additive can include a plurality of environmentally acceptable nanoparticles. The particle size distribution of the plurality of nanoparticles can be selected such that the nanoparticles stabilize a wellbore wall of a subterranean formation or form a filtercake to inhibit or prevent fluid loss into permeable areas of the formation. The plurality of nanoparticles can have a particle size distribution of a d10 value in the range of 20 to 45 nanometers, a d50 value in the range of 40 to 80 nanometers, and a d90 value in the range of 80 to 140 nanometers. The plurality of nanoparticles can also be coated with a polymeric shell. The treatment fluid can be used in an oil and gas operation.

Abstract: Methods and compositions comprising nanoparticle additives for use in drilling and treatment fluid compositions are provided. In some embodiments the present disclosure includes providing a treatment fluid including an aqueous base fluid, a nanoparticle additive, and a viscosifier; introducing the treatment fluid into at least a portion of a subterranean formation to contact at least a portion of the subterranean formation; and allowing the treatment fluid to reduce fluid loss into the subterranean formation.

Abstract: Disclosed herein is a wellbore servicing fluid including an aqueous fluid, an oil, and a compound according to Structure I or Structure II. The wellbore servicing fluid can be used as a drilling fluid in a method of servicing a wellbore penetrating a subterranean formation. The wellbore servicing fluid can have an increased emulsion stability, a reduced dilution and waste volume, and can reduce fluid loss and/or salt washout when drilling though certain subterranean formations such as salt domes.

Abstract: Methods and compositions for using shale inhibitor additives in subterranean formations, and specifically, to dried shale inhibitor additives and methods for use are provided. In one embodiment, the methods include providing a dried shale inhibitor additive that includes a precipitate of at least one liquid amine shale inhibitor; allowing at least a portion of the dried shale inhibitor additive to dissolve in a treatment fluid including an aqueous base fluid; and introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation.

Abstract: Treatment fluids and methods of using a treatment fluid for minimizing fluid loss in a wellbore are disclosed. A method may comprise providing a drill-in fluid. The drill-in fluid may comprise an aqueous liquid, a base oil, a polyol, an emulsifying surfactant, and a solid bridging agent. The method may further comprise circulating the drill-in fluid through a drill-string and past a drill bit. The method may further comprise drilling in a reservoir section of a subterranean formation to extend a wellbore in the reservoir section the drill-in fluid is circulated therein.

Abstract: Methods of treating a subterranean formation including shale include preparing a treatment fluid by mixing an aqueous base fluid and a dry polyvinyl pyrrolidone (PVP) in flake or powder form having a molecular weight between about 500,000 and about 2,000,000 and introducing the treatment fluid in the subterranean formation.

Abstract: A method of reducing a density of a density of a stable emulsion drilling fluid may comprise providing a stable emulsion drilling fluid comprising: an aqueous liquid; a biopolymer; an emulsifier; solid particulates; and an oil; wherein the stable emulsion drilling fluid is capable of remaining in quiescent storage at approximately 70° F. and atmospheric pressure without phase separation for about 8 hours or longer; circulating the stable emulsion drilling fluid though a drill string and annulus; adding additional oil to the stable emulsion drilling fluid to decrease the density of the stable emulsion drilling fluid and produce a reduced density stable emulsion drilling fluid; and circulating the reduced density stable emulsion drilling fluid though the drill string and the annulus.

Abstract: The embodiments of the present disclosure relate generally to subterranean formation operations and, more particularly, to milling oilfield particulates for use in subterranean formation operations. The embodiments provide systems and methods which may include jet mills that can be customized to grind desirably sized crude oilfield particulates, thereby creating operational oilfield particulates, and containerized for ease of use, movement, and shipping.

Abstract: Various embodiments disclosed relate to methods of cleaning invert emulsion drilling fluids. In various embodiments, the present invention provides a method of cleaning a drilling fluid. The method includes cleaning a used invert emulsion drilling fluid that includes drilled cuttings to form a cleaned invert emulsion drilling fluid. The cleaning includes processing the used invert emulsion drilling fluid in a separator to remove at least some of the drilled cuttings therefrom.

Abstract: A method of reducing a density of a density of a stable emulsion drilling fluid may comprise providing a stable emulsion drilling fluid comprising: an aqueous liquid; a biopolymer; an emulsifier; solid particulates; and an oil; wherein the stable emulsion drilling fluid is capable of remaining in quiescent storage at approximately 70° F. and atmospheric pressure without phase separation for about 8 hours or longer; circulating the stable emulsion drilling fluid though a drill string and annulus; adding additional oil to the stable emulsion drilling fluid to decrease the density of the stable emulsion drilling fluid and produce a reduced density stable emulsion drilling fluid; and circulating the reduced density stable emulsion drilling fluid though the drill string and the annulus.

Abstract: The present disclosure may be directed to treatment fluids and methods of using a treatment fluid for minimizing fluid loss in a wellbore. An example method may comprise providing a drill-in fluid. The drill-in fluid may comprise an aqueous liquid, a base oil, a polyol, an emulsifying surfactant, and a solid bridging agent. The method may further comprise circulating the drill-in fluid through a drill-string and past a drill bit. The method may further comprise drilling in a reservoir section of a subterranean formation to extend a wellbore in the reservoir section the drill-in fluid is circulated therein.

Abstract: Provided are compositions, systems, and methods of using a synthetic latex composition for treating a subterranean formation. An example method comprises providing a synthetic latex composition comprising: a synthetic latex and a latex stabilizer; and exposing the synthetic latex composition to air for an exposure period of at least one day; wherein the synthetic latex composition loses less than 5% of its initial water concentration at the end of a one-day exposure period. The synthetic latex composition may be further included in a treatment fluid. The treatment fluid may be introduced into a wellbore penetrating a subterranean formation.

Abstract: Proactive multiple controlled-environment facility investigative data aggregation and analysis systems and methods employ controlled-environment facility communications management systems, each associated with at least one controlled-environment facility, and a centralized investigative data aggregation and analysis system. The communications management systems each capture data related to communications associated with each resident of each facility and provide financial data related to resident accounts. The centralized investigative data aggregation and analysis system receives the captured data and/or financial data and identifies suspicious activity based on voice biometric analysis, communication analysis, location of calls, the financial data, and/or the like.