Abstract: Nano- and micro-particles (NMP) can be formed from an oil/water emulsion. The emulsion is made by mixing a liquid solvent, at least one surfactant, a particle-forming compound, and at least curing agent. If desired, pH control agents and viscosity enhancers can be added to the liquid solvent. The particle-forming compound and the curing agents are mixed together and form the oil phase in the emulsion and after curing, the particles are formed. The nano- and micro-particles can be used as proppant to enhance the conductivity of nano- and microfractures and fluid-loss-control additive for hydraulic fracturing operations.

Abstract: A method and an apparatus for sharing an App, an electronic device and a storage medium are provided. The method includes in response to detecting a preset trigger operation for an App, displaying associated regions for associated devices; in response to a selecting operation for any of the associated regions, determining an associated device corresponding to the any of the associated regions as a target device; and sending interface display data of the App to the target device, so that the target device displays a program interface of the App based on the received interface display data.

Abstract: Nano- and micro-particles (NMP) can be formed from an oil/water emulsion. The emulsion is made by mixing a liquid solvent, at least one surfactant, a particle-forming compound, and at least curing agent. If desired, pH control agents and viscosity enhancers can be added to the liquid solvent. The particle-forming compound and the curing agents are mixed together and form the oil phase in the emulsion and after curing, the particles are formed. The nano- and micro-particles can be used as proppant to enhance the conductivity of nano- and microfractures and fluid-loss-control additive for hydraulic fracturing operations.

Abstract: Nano- and micro-particles (NMP) can be formed from an oil/water emulsion. The emulsion is made by mixing a liquid solvent, at least one surfactant, a particle-forming compound, and at least curing agent. If desired, pH control agents and viscosity enhancers can be added to the liquid solvent. The particle-forming compound and the curing agents are mixed together and form the oil phase in the emulsion and after curing, the particles are formed. The nano- and micro-particles can be used as proppant to enhance the conductivity of nano- and microfractures and fluid-loss-control additive for hydraulic fracturing operations.

Abstract: The present disclosure provides non-planar cutting tooth and a diamond drill bit. The non-planar cutting tooth comprises a base, a table connected to a top of the base. a concave shaped surface on the center portion of a top surface of the table; three cutting ridges with each extending from a vertex of the concave shaped surface to an outer edge of the top surface; three cutting bevels with each locating between two cutting ridges of the three cutting ridges; each of the three cutting ridges has a fillet.

Abstract: An emulsifying composition for an oil based drilling fluid includes oleyl alcohol and a mixture of polymeric amides. The polymeric amides can be 1,3-dihydroxypropan-2-yl (E)-12-hydroxyoctadec-9-enoate, (9E,9?E)-N,N?-(azanediylbis(ethane-2,1-diyl))bis(12-hydroxyoctadec-9-enamide, (E)-12-hydroxy-N,N-bis(2-((E)-12-hydroxyoctadec-9-enamido(ethyl)octadec-9-enamide, (Z)-4-(bis(2-((E)-12-hydroxyoctadec-9-enamido)ethy)amino)-4-oxobut-2-enoic acid, 1,3-dihydroxypropan-2-yl(Z)-4-(bis(2-((E)-12-hydroxyoctadec-9-enamido)ethy)amino)-4-oxobut-2-enoate, and N1,N1,N4,N4-tetrakis(2-((E)-12-hydroxyoctadec-9-enamido)ethyl)maleamide. The method of forming the emulsifying composition includes reacting a fatty oil with diethylenetriamine and then maleic acid, and adding oleyl alcohol. The high density emulsifying composition is stable at high temperatures of drilling operations at greater depths in the wellbore.

Abstract: The present disclosure provides non-planar cutting tooth and a diamond drill bit. The non-planar cutting tooth comprises a base, a table connected to a top of the base. a concave shaped surface on the center portion of a top surface of the table; three cutting ridges with each extending from a vertex of the concave shaped surface to an outer edge of the top surface; three cutting bevels with each locating between two cutting ridges of the three cutting ridges; each of the three cutting ridges has a fillet.

Abstract: The method for well-stimulation through a wellbore in a rock formation is hydraulic fracturing under high temperature conditions. The method includes injecting a fracturing fluid system to the rock formation; fracturing the rock formation at a temperature between 150-260 degrees Celsius; and recovering fluid components of the fracturing fluid system from the wellbore and setting the proppant in the fractures. The fracturing fluid system includes proppant and a plurality of fluid components. The fluid components can include water, a gelling agent, and a stabilizer made of ascorbic acid ranging from 50-100 ppt so as to adjust pH and delay said cross linking agent.

Abstract: Nano- and micro-particles (NMP) can be formed from an oil/water emulsion. The emulsion is made by mixing a liquid solvent, at least one surfactant, a particle-forming compound, and at least curing agent. If desired, pH control agents and viscosity enhancers can be added to the liquid solvent. The particle-forming compound and the curing agents are mixed together and form the oil phase in the emulsion and after curing, the particles are formed. The nano- and micro-particles can be used as proppant to enhance the conductivity of nano- and microfractures and fluid-loss-control additive for hydraulic fracturing operations.

Abstract: The method for well-stimulation through a wellbore in a rock formation is hydraulic fracturing under high temperature conditions. The method includes injecting a fracturing fluid system to the rock formation; fracturing the rock formation at a temperature between 150-260 degrees Celsius; and recovering fluid components of the fracturing fluid system from the wellbore and setting the proppant in the fractures. The fracturing fluid system includes proppant and a plurality of fluid components. The fluid components can include water, a gelling agent, and a stabilizer made of ascorbic acid ranging from 50-100 ppt so as to adjust pH and delay said cross linking agent.

Abstract: The method for well-stimulation through a wellbore in a rock formation is hydraulic fracturing under high temperature conditions. The method includes injecting a fracturing fluid system to the rock formation; fracturing the rock formation at a temperature between 150-260 degrees Celsius; and recovering fluid components of the fracturing fluid system from the wellbore and setting the proppant in the fractures. The fracturing fluid system includes proppant and a plurality of fluid components. The fluid components can include water, a gelling agent, and a stabilizer made of ascorbic acid ranging from 50-100 ppt so as to adjust pH and delay said cross linking agent.

Abstract: An emulsifying composition for an oil based drilling fluid includes oleyl alcohol and a mixture of polymeric amides. The polymeric amides can be 1,3-dihydroxypropan-2-yl (E)-12-hydroxyoctadec-9-enoate, (9E,9?E)-N,N?-(azanediylbis(ethane-2,1-diyl))bis(12-hydroxyoctadec-9-enamide, (E)-12-hydroxy-N,N-bis(2-((E)-12-hydroxyoctadec-9-enamido(ethyl)octadec-9-enamide, (Z)-4-(bis(2-((E)-12-hydroxyoctadec-9-enamido)ethy)amino)-4-oxobut-2-enoic acid, 1,3-dihydroxypropan-2-yl(Z)-4-(bis(2-((E)-12-hydroxyoctadec-9-enamido)ethy)amino)-4-oxobut-2-enoate, and N1,N1,N4,N4-tetrakis(2-((E)-12-hydroxyoctadec-9-enamido)ethyl)maleamide. The method of forming the emulsifying composition includes reacting a fatty oil with diethylenetriamine and then maleic acid, and adding oleyl alcohol. The high density emulsifying composition is stable at high temperatures of drilling operations at greater depths in the wellbore.

Abstract: The method for well-stimulation through a wellbore in a rock formation is hydraulic fracturing under high temperature conditions. The method includes injecting a fracturing fluid system to the rock formation; fracturing the rock formation at a temperature between 150-260 degrees Celsius; and recovering fluid components of the fracturing fluid system from the wellbore and setting the proppant in the fractures. The fracturing fluid system includes proppant and a plurality of fluid components. The fluid components can include water, a gelling agent, and a stabilizer made of ascorbic acid ranging from 50-100 ppt so as to adjust pH and delay said cross linking agent.

Abstract: An emulsifying composition for an oil based drilling fluid includes oleyl alcohol and a mixture of polymeric amides. The polymeric amides can be 1,3-dihydroxypropan-2-yl (E)-12-hydroxyoctadec-9-enoate, (9E,9?E)-N,N?-(azanediylbis(ethane-2,1-diyl))bis(12-hydroxyoctadec-9-enamide, (E)-12-hydroxy-N,N-bis(2-((E)-12-hydroxyoctadec-9-enamido(ethyl)octadec-9-enamide, (Z)-4-(bis(2-((E)-12-hydroxyoctadec-9-enamido)ethy)amino)-4-oxobut-2-enoic acid, 1,3-dihydroxypropan-2-yl(Z)-4-(bis(2-((E)-12-hydroxyoctadec-9-enamido)ethy)amino)-4-oxobut-2-enoate, and N1,N1,N4,N4-tetrakis(2-((E)-12-hydroxyoctadec-9-enamido)ethyl)maleamide. The method of forming the emulsifying composition includes reacting a fatty oil with diethylenetriamine and then maleic acid, and adding oleyl alcohol. The high density emusifying composition is stable at high temperatures of drilling operations at greater depths in the wellbore.

Abstract: The method for well-stimulation through a wellbore in a rock formation is hydraulic fracturing under high temperature conditions. The method includes injecting a fracturing fluid system to the rock formation; fracturing the rock formation at a temperature between 150-260 degrees Celsius; and recovering fluid components of the fracturing fluid system from the wellbore and setting the proppant in the fractures. The fracturing fluid system includes proppant and a plurality of fluid components. The fluid components can include water, a gelling agent, and a stabilizer made of ascorbic acid. The ascorbic acid stabilizes viscosity of the gelling agent, adjusts pH, and delays cross linking. Amount of components and additional components, such as a cross-linking agent, a breaker, another adjusting agent and an inverting surfactant adjust the fracturing fluid system for well conditions and a type of treatment to be completed.

Abstract: The method for well-stimulation through a wellbore in a rock formation is hydraulic fracturing under high temperature conditions. The method includes injecting a fracturing fluid system to the rock formation; fracturing the rock formation at a temperature between 150-260 degrees Celsius; and recovering fluid components of the fracturing fluid system from the wellbore and setting the proppant in the fractures. The fracturing fluid system includes proppant and a plurality of fluid components. The fluid components can include water, a gelling agent, and a stabilizer made of ascorbic acid. The ascorbic acid stabilizes viscosity of the gelling agent, adjusts pH, and delays cross linking. Amount of components and additional components, such as a cross-linking agent, a breaker, another adjusting agent and an inverting surfactant adjust the fracturing fluid system for well conditions and a type of treatment to be completed.

Abstract: An emulsifying composition for an oil based drilling fluid includes oleyl alcohol and a mixture of polymeric amides. The polymeric amides can be 1,3-dihydroxypropan-2-yl (E)-12-hydroxyoctadec-9-enoate, (9E,9? E)-N,N?-(azanediylbis(ethane-2,1-diyl))bis(12-hydroxyoctadec-9-enamide, (E)-12-hydroxy-N,N-bis(2-((E)-12-hydroxyoctadec-9-enamido(ethyl)octadec-9-enamide, (Z)-4-(bis(2-((E)-12-hydroxyoctadec-9-enamido)ethy)amino)-4-oxobut-2-enoic acid, 1,3-dihydroxypropan-2-yl(Z)-4-(bis(2-((E)-12-hydroxyoctadec-9-enamido)ethy)amino)-4-oxobut-2-enoate, and N1,N1,N4,N4-tetrakis(2-((E)-12-hydroxyoctadec-9-enamido)ethyl)maleamide. The method of forming the emulsifying composition includes reacting a fatty oil with diethylenetriamine and then maleic acid, and adding oleyl alcohol. The high density emusifying composition is stable at high temperatures of drilling operations at greater depths in the wellbore.

Abstract: The method for well-stimulation through a wellbore in a rock formation is hydraulic fracturing under high temperature conditions. The method includes injecting a fracturing fluid system to the rock formation; fracturing the rock formation at a temperature between 150-260 degrees Celsius; and recovering fluid components of the fracturing fluid system from the wellbore and setting the proppant in the fractures. The fracturing fluid system includes proppant and a plurality of fluid components. The fluid components can include water, a gelling agent, and a stabilizer made of ascorbic acid. The ascorbic acid stabilizes viscosity of the gelling agent, adjusts pH, and delays cross linking. Amount of components and additional components, such as a cross-linking agent, a breaker, another adjusting agent and an inverting surfactant adjust the fracturing fluid system for well conditions and a type of treatment to be completed.

Abstract: An emulsifying composition for an oil based drilling fluid includes oleyl alcohol and a mixture of polymeric amides. The polymeric amides can be 1,3-dihydroxypropan-2-yl (E)-12-hydroxyoctadec-9-enoate, (9E,9?E)-N,N?-(azanediylbis(ethane-2,1-diyl))bis(12-hydroxyoctadec-9-enamide, (E)-12-hydroxy-N,N-bis(2-((E)-12-hydroxyoctadec-9-enamido(ethyl)octadec-9-enamide, (Z)-4-(bis(2-((E)-12-hydroxyoctadec-9-enamido)ethy)amino)-4-oxobut-2-enoic acid, 1,3-dihydroxypropan-2-yl(Z)-4-(bis(2-((E)-12-hydroxyoctadec-9-enamido)ethy)amino)-4-oxobut-2-enoate, and N1,N1,N4,N4-tetrakis(2-((E)-12-hydroxyoctadec-9-enamido)ethyl)maleamide. The method of forming the emulsifying composition includes reacting a fatty oil with diethylenetriamine and then maleic acid, and adding oleyl alcohol. The high density emulsifying composition is stable at high temperatures of drilling operations at greater depths in the wellbore.

Abstract: The method for well-stimulation through a wellbore in a rock formation is hydraulic fracturing under high temperature conditions. The method includes injecting a fracturing fluid system to the rock formation; fracturing the rock formation at a temperature between 150-260 degrees Celsius; and recovering fluid components of the fracturing fluid system from the wellbore and setting the proppant in the fractures. The fracturing fluid system includes proppant and a plurality of fluid components. The fluid components can include water, a gelling agent, and a stabilizer made of ascorbic acid. The ascorbic acid stabilizes viscosity of the gelling agent, adjusts pH, and delays cross linking. Amount of components and additional components, such as a cross-linking agent, a breaker, another adjusting agent and an inverting surfactant adjust the fracturing fluid system for well conditions and a type of treatment to be completed.