Abstract: A wellbore fluid may include an oleaginous fluid forming a continuous phase; a non-oleaginous fluid forming a discontinuous phase; at least one emulsifier stabilizing an emulsion of the non-oleaginous continuous phase within the oleaginous continuous phase; and at least one viscosifier dispersed into the oleaginous continuous phase in a concentration of at least 4 ppb; wherein upon subjecting the wellbore fluid to shear rate of at least 10,000 s?1, the emulsion is disrupted and the non-oleaginous fluid contacts the at least one viscosifier, thereby solidifying the wellbore fluid.

Abstract: A wellbore fluid may include an oleaginous fluid forming a continuous phase; a non-oleaginous fluid forming a discontinuous phase; at least one emulsifier stabilizing an emulsion of the non-oleaginous continuous phase within the oleaginous continuous phase; and at least one viscosifier dispersed into the oleaginous continuous phase in a concentration of at least 4 ppb; wherein upon subjecting the wellbore fluid to shear rate of at least 10,000 s-1, the emulsion is disrupted and the non-oleaginous fluid contacts the at least one viscosifier, thereby solidifying the wellbore fluid.

Abstract: A wellbore fluid may include an oleaginous fluid forming a continuous phase; a non-oleaginous fluid forming a discontinuous phase; at least one emulsifier stabilizing an emulsion of the non-oleaginous continuous phase within the oleaginous continuous phase; and at least one viscosifier dispersed into the oleaginous continuous phase in a concentration of at least 4 ppb; wherein upon subjecting the wellbore fluid to shear rate of at least 10,000 s?1, the emulsion is disrupted and the non-oleaginous fluid contacts the at least one viscosifier, thereby solidifying the wellbore fluid.

Abstract: A method of reducing fluid loss includes pumping a wellbore fluid including resin coated solid particulate into a wellbore having fractures therein, the resin coated solid particulate forming a substantially impermeable plug in the fractures. A method of drilling a wellbore includes drilling a wellbore through a formation using a first wellbore fluid; and upon experiencing a fluid loss event to the formation, pumping a second wellbore fluid including resin coated solid particulates into the wellbore.

Abstract: Wellbore fluids, and methods of use thereof, are disclosed. Wellbore fluids may include a non-oleaginous internal phase; an oleaginous external phase; at least one two-dimensional platelet-like material; a first latex-containing copolymer comprising at least one copolymer formed from at least one natural polymer and at least one latex monomer; and a second latex polymer distinct from the first latex polymer.

Abstract: A wellbore fluid may include an oleaginous fluid forming a continuous phase; a non-oleaginous fluid forming a discontinuous phase; at least one emulsifier stabilizing an emulsion of the non-oleaginous continuous phase within the oleaginous continuous phase; and at least one viscosifier dispersed into the oleaginous continuous phase in a concentration of at least 4 ppb; wherein upon subjecting the wellbore fluid to shear rate of at least 10,000 s-1, the emulsion is disrupted and the non-oleaginous fluid contacts the at least one viscosifier, thereby solidifying the wellbore fluid.

Abstract: Wellbore fluids, and methods of use thereof, are disclosed. Wellbore fluids may include a non-oleaginous internal phase, an oleaginous external phase, a first latex-containing copolymer comprising at least one copolymer formed from at least one natural polymer and at least one latex monomer, and a second latex polymer distinct from the first latex polymer.

Abstract: A wellbore fluid may include a base fluid and milled polymeric fibers, wherein the base fluid is an oil-based fluid or an aqueous-based fluid, and wherein the milled polymeric fibers may have a length distribution in which the lowest point in the length distribution is up to about 50% of the average fiber length.

Abstract: A mobility enhancing device in the form of an exoskeleton provides mobility assistance or enhancement to a user within the exoskeleton. The exoskeleton may include a torso support and two leg supports coupled to the torso support. Each leg support may include a hip joint, a knee joint, a foot module, and panels connecting the torso support to the hip joints, the hip joints to the knee joints, and the knee joints to the foot modules. Actuators such as motors may be positioned in a discrete location on exoskeleton away from the relatively bulky knee and hip joints to provide for a low profile of the exoskeleton, which may allow the exoskeleton to be worn inconspicuously under a user's clothing.

Abstract: A method of reducing fluid loss includes pumping a wellbore fluid including resin coated solid particulate into a wellbore having fractures therein, the resin coated solid particulate forming a substantially impermeable plug in the fractures. A method of drilling a wellbore includes drilling a wellbore through a formation using a first wellbore fluid; and upon experiencing a fluid loss event to the formation, pumping a second wellbore fluid including resin coated solid particulates into the wellbore.

Abstract: A fracture insert is disclosed including a first cylindrical portion and a second cylindrical portion disposed opposite the first cylindrical portion defining a radial gap therebetween to form an axial flow channel. The axial flow channel provides a flow path for a drilling fluid from a top of the cylindrical portions to a bottom of the cylindrical portions and the radial gap provides a flow path for the drilling fluid from the axial flow channel to a radial terminus of the first cylindrical portion and the second cylindrical portion.

Abstract: A wellbore fluid may include a base fluid and milled polymeric fibers, wherein the base fluid is an oil-based fluid or an aqueous-based fluid, and wherein the milled polymeric fibers may have a length distribution in which the lowest point in the length distribution is up to about 50% of the average fiber length.

Abstract: A method for using a drilling fluid test device including a test cell including a perforated plate disposed proximate a first end of the test cell, a piston disposed within the cell, a first chamber formed between the perforated plate and the piston, the first chamber configured to receive lost circulation material (LCM), a second chamber formed between the piston and a second end of the test cell, the piston providing a seal between the first and second chambers, a fluid inlet disposed proximate the second end of the test cell configured to introduce fluid into a second chamber of the test cell, a filtrate outlet disposed proximate the first end of the test cell to discharge filtrate, and a pump in communication with the fluid inlet.

Abstract: A method for testing a loss control material, the method including filling a testing environment in a testing system with a first fluid, injecting a loss control material in a second fluid into the testing environment from a first end of the testing system, thereby displacing the first fluid across the testing environment to a second end of the testing system, and monitoring a formation of a barrier created by the loss control material.

Abstract: A method that includes pulling a sled disposed on a trough across a first filtercake at a constant speed, measuring a force versus distance or time based on the pulling; and outputting a frictional force curve is described. An apparatus that includes a base, a pulley attached to the base, a trough attached to the base, a sled disposed on the trough, a cable connecting the pulley and the sled, the cable connected to an arm capable of being moved at a constant speed, and a system to measure the force required to move the sled is also described.

Abstract: Wellbore fluids, and methods of use thereof, are disclosed. Wellbore fluids may include a non-oleaginous internal phase; an oleaginous external phase; at least one two-dimensional platelet-like material; a first latex-containing copolymer comprising at least one copolymer formed from at least one natural polymer and at least one latex monomer; and a second latex polymer distinct from the first latex polymer.

Abstract: Wellbore fluids, and methods of use thereof, are disclosed. Wellbore fluids may include a non-oleaginous internal phase, an oleaginous external phase, a first latex-containing copolymer comprising at least one copolymer formed from at least one natural polymer and at least one latex monomer, and a second latex polymer distinct from the first latex polymer.

Abstract: A mobility enhancing device in the form of an exoskeleton provides mobility assistance or enhancement to a user within the exoskeleton. The exoskeleton may include a torso support and two leg supports coupled to the torso support. Each leg support may include a hip joint, a knee joint, a foot module, and panels connecting the torso support to the hip joints, the hip joints to the knee joints, and the knee joints to the foot modules. Actuators such as motors may be positioned in a discrete location on exoskeleton away from the relatively bulky knee and hip joints to provide for a low profile of the exoskeleton, which may allow the exoskeleton to be worn inconspicuously under a user's clothing.

Abstract: A method for testing a loss control material, the method including filling a testing environment in a testing system with a first fluid, injecting a loss control material in a second fluid into the testing environment from a first end of the testing system, thereby displacing the first fluid across the testing environment to a second end of the testing system, and monitoring a formation of a barrier created by the loss control material.

Abstract: A fracture insert is disclosed including a first cylindrical portion and a second cylindrical portion disposed opposite the first cylindrical portion defining a radial gap therebetween to form an axial flow channel. The axial flow channel provides a flow path for a drilling fluid from a top of the cylindrical portions to a bottom of the cylindrical portions and the radial gap provides a flow path for the drilling fluid from the axial flow channel to a radial terminus of the first cylindrical portion and the second cylindrical portion.