Abstract: A display substrate, a manufacturing method thereof, and a display device are provided. A pixel region is provided with a light emission function layer on a base substrate of the display substrate, and a separation region is provided with at least one first barrier structure. The first barrier structure includes a stopper pattern and a first separation component. A side surface of the first separation component has a recess, and a portion of the light emission function layer extending to the separation region is disconnected on the side of the first separation component. The separation region is provided with an inorganic layer structure on the base substrate. The inorganic layer structure includes multiple stacked inorganic film layers, the stopper pattern is located between two adjacent inorganic film layers and the first separation component is located on a side of the inorganic layer structure away from the base substrate.

Abstract: The present disclosure provides a master manipulator. The master manipulator may include an arm assembly including at least one arm joint mechanism and a wrist assembly movably connected with the arm assembly. The wrist assembly may allow an operator to perform a corresponding operation. The wrist assembly may include at least one wrist joint mechanism. The master manipulator may also include a support assembly configured to support at least one of the arm assembly and the wrist assembly.

Abstract: Embodiments of the present disclosure provide a robot and a master manipulator thereof. The master manipulator includes: an end control assembly; and an attitude adjustment assembly. The attitude adjustment assembly may include a first mechanism and a second mechanism, the first mechanism and the second mechanism are connected to the end control assembly, and the end control assembly controls the first mechanism and the second mechanism to move through the connection between the first mechanism and end control assembly and the connection between the second mechanism and the end control assembly.

Abstract: A display panel, a method for manufacturing the display panel, and a display apparatus are described. In an embodiment, the display panel includes a display area and a non-display area; a substrate; an organic layer located at a side of the substrate and located in the display area and the non-display area, in which the organic layer includes a first portion located in the non-display area; and an organic layer protection structure located on a surface of the organic layer facing away from the substrate. In an embodiment, the organic layer protection structure includes a first structure in the display area and a second structure in the non-display area. In an embodiment, the second structure overlaps the first portion in a direction perpendicular to a plane of the substrate. In an embodiment, the first structure and the second structure are in direct contact with the organic layer.

Abstract: Methods may include introducing a polymerizable composition containing a polycyclic monomer and a catalyst into a subterranean formation; and polymerizing the polymerizable composition in the presence of the catalyst in situ to form a polymer. Methods may also include lowering a wellbore tool into the subterranean formation, wherein the tool contains a first partition containing a polymerizable composition, and a second partition containing a catalyst; releasing the polymerizable composition from the first partition; releasing the catalyst from the second partition; contacting the polymerizable composition and the catalyst in a mixing region; and reacting the polymerizable composition and the catalyst in situ to form a polymer.

Abstract: Embodiments may generally take the form of a degradable composite structure and a method for controlling the rate of degradation of a degradable composite structure. An example embodiment may take the form of a degradable polymer matrix composite (PMC) including a matrix having: a degradable polymer, a fiber reinforcement, and particulate fillers. The fiber loading is between approximately 10% to 70% by weight and the particulate loading is between approximately 5% to 60%.

Abstract: Methods include introducing a multistage treatment fluid into one or more intervals of a wellbore, wherein the treatment fluid contains one or more stages of a polymer-forming composition and one or more stages of a spacer fluid and initiating polymerization of the one or more stages of polymer-forming composition. Methods may include designing a multistage treatment fluid containing one or more stages of a polymer-forming composition and one or more stages of a spacer fluid, wherein or more stages of the polymer-forming composition comprises a thermosetting polymer; and pumping the multistage treatment fluid into a wellbore, wherein the pumping rate is determined by constructing a model based upon (a) the minimum pumping rate determined from the critical reaction temperature and the downhole temperature, (b) the fracture closing time, (c) the temperature within one or more fractures, and (d) the maximum pumping rate.

Abstract: Methods of treating a subterranean formation penetrated by a wellbore may include injecting a multistage fracturing treatment into the wellbore comprising one or more stages of geopolymer precursor composition containing a geopolymer precursor and an activator, and one or more stages of a spacer fluid; and curing the one or more stages of geopolymer precursor composition. In another aspect, methods of treating a subterranean formation penetrated by a wellbore may include injecting a multistage fracturing treatment into the wellbore that include one or more stages of geopolymer precursor composition, wherein the geopolymer precursor composition includes an emulsion having an oleaginous external phase, and an internal phase comprising one or more surfactants, a geopolymer precursor, and an activator, and one or more stages of a spacer fluid; and curing the one or more stages of geopolymer precursor composition.

Abstract: Procedures include designing parameters for cementation jobs based upon the wellbore geometries and loading conditions. The cementation parameters such as Young's modulus are selected such that longitudinal crack propagation is inhibited. Procedures also include determining critical loading conditions for an already-cemented casing annulus based upon the specified cement properties and wellbore conditions. The critical loading conditions are determined such that longitudinal crack propagation in the cement is inhibited. Techniques are used to improve the friction coefficients between the casing and cement to inhibit longitudinal crack propagation. The treatments can include forming surface patterns that enhance friction and/or making the casing surface oleophopic and/or hydrophilic.

Abstract: Methods may include introducing a polymerizable composition containing a polycyclic monomer and a catalyst into a subterranean formation; and polymerizing the polymerizable composition in the presence of the catalyst in situ to form a polymer. Methods may also include lowering a wellbore tool into the subterranean formation, wherein the tool contains a first partition containing a polymerizable composition, and a second partition containing a catalyst; releasing the polymerizable composition from the first partition; releasing the catalyst from the second partition; contacting the polymerizable composition and the catalyst in a mixing region; and reacting the polymerizable composition and the catalyst in situ to form a polymer.

Abstract: Methods of treating a subterranean formation penetrated by a wellbore may include injecting a multistage fracturing treatment into the wellbore comprising one or more stages of geopolymer precursor composition containing a geopolymer precursor and an activator, and one or more stages of a spacer fluid; and curing the one or more stages of geopolymer precursor composition. In another aspect, methods of treating a subterranean formation penetrated by a wellbore may include injecting a multistage fracturing treatment into the wellbore that include one or more stages of geopolymer precursor composition, wherein the geopolymer precursor composition includes an emulsion having an oleaginous external phase, and an internal phase comprising one or more surfactants, a geopolymer precursor, and an activator, and one or more stages of a spacer fluid; and curing the one or more stages of geopolymer precursor composition.

Abstract: Methods include introducing a multistage treatment fluid into one or more intervals of a wellbore, wherein the treatment fluid contains one or more stages of a polymer-forming composition and one or more stages of a spacer fluid and initiating polymerization of the one or more stages of polymer-forming composition. Methods may include designing a multistage treatment fluid containing one or more stages of a polymer-forming composition and one or more stages of a spacer fluid, wherein or more stages of the polymer-forming composition comprises a thermosetting polymer; and pumping the multistage treatment fluid into a wellbore, wherein the pumping rate is determined by constructing a model based upon (a) the minimum pumping rate determined from the critical reaction temperature and the downhole temperature, (b) the fracture closing time, (c) the temperature within one or more fractures, and (d) the maximum pumping rate.

Abstract: Methods may include treating a subterranean formation penetrated by a wellbore, including: pumping a treatment fluid containing one or more polymeric proppants into the formation at a pressure sufficient to initiate a fracture, wherein the one or more polymeric proppants are composed of one or more polymers selected from a group of polyethylene, polypropylene, butylene, polystyrenes (PS) and copolymers thereof, high-impact grafted polystyrene (HIPS), acrylic polymers, methacrylic polymers, polyvinyl chloride (PVC), polyvinyl acetate (PVA), polycarbonate (PC), hydrogenated nitrile butadiene rubber (HNBR), ethyelene propylene diene monomer (EPDM), polydimethylsiloxane (PDMS), natural rubber, polystyrene-polybutadiene (PS-PB) copolymers, polymethylmethacrylate (PMMA), polystyrene-block-polymethylmethacrylate (PS-b-PMMA), acrylonitrile butadiene styrene (ABS), and epoxy resins.

Abstract: Methods may include contacting a degradable polymer in a wellbore traversing a subterranean formation with a treatment fluid, wherein the treatment fluid is formulated with one or more polymer degrading catalysts; and allowing the degradable polymer composite to at least partially degrade. In another aspect, methods may be directed to designing a wellbore treatment that includes determining at least one degradation characteristic for one or more degradable polymers; formulating an aqueous treatment fluid based on the determined values, wherein the aqueous treatment fluid comprises one or more polymer degrading catalysts; contacting the degradable polymer with an aqueous fluid; and allowing the degradable polymer to at least partially degrade the degradable polymer.

Abstract: Embodiments may generally take the form of a degradable composite structure and a method for controlling the rate of degradation of a degradable composite structure. An example embodiment may take the form of a degradable polymer matrix composite (PMC) including a matrix having: a degradable polymer, a fiber reinforcement, and particulate fillers. The fiber loading is between approximately 10% to 70% by weight and the particulate loading is between approximately 5% to 60%.

Abstract: Degradation agent encapsulation is provided. In one possible implementation, a capsule includes a degradation agent configured to encourage degradation of the part and a coating at least partially encapsulating the degradation agent. The coating is engineered to be compromised upon exposure to one or more activation triggers. In another possible implementation, a degradable part includes one or more capsules embedded in the part. The capsules include a degradation agent at least partially encapsulated in a coating engineered to be compromised upon exposure to one or more activation triggers.

Abstract: Procedures include designing parameters for cementation jobs based upon the wellbore geometries and loading conditions. The cementation parameters such as Young's modulus are selected such that longitudinal crack propagation is inhibited. Procedures also include determining critical loading conditions for an already-cemented casing annulus based upon the specified cement properties and wellbore conditions. The critical loading conditions are determined such that longitudinal crack propagation in the cement is inhibited. Techniques are used to improve the friction coefficients between the casing and cement to inhibit longitudinal crack propagation. The treatments can include forming surface patterns that enhance friction and/or making the casing surface oleophopic and/or hydrophilic.

Abstract: Embodiments may include methods that include emplacing a degradable material into a wellbore, wherein the degradable material includes a thermoplastic elastomer; contacting the degradable material with an aqueous fluid downhole; and allowing the degradable material to at least partially degrade. In another aspect, methods may include emplacing into a wellbore a tool containing a sealing element thereon, wherein the sealing element contains a degradable material; engaging the sealing element with a downhole surface to establish a seal; contacting the sealing element with an aqueous fluid; and allowing the sealing element to at least partially degrade, thereby disrupting the established seal.

Abstract: A composition comprising, and methods of producing a solid state dispersion comprising particles dispersed in a water soluble polymer. Treatment fluids comprising, and methods of using the solid state dispersion are also disclosed.

Abstract: A composition comprising, and methods of producing a solid state dispersion comprising particles dispersed in a water soluble polymer. Treatment fluids comprising, and methods of using the solid state dispersion are also disclosed.