Abstract: An angle grinder comprises a motor and an output member to which a grinding disc is attachable. The output member defines an output axis. A drive shaft is configured to transfer torque from the motor to the output member. A braking disc is coupled to the drive shaft and a braking pad is moveable in a direction transverse to the drive axis between a first braking pad position and a second braking pad position, in which the braking pad is not in contact with the braking disc. A biasing member biases the braking pad toward the first braking pad position and a trigger is pivotable about a trigger axis between a first trigger position and a second trigger position. In response to the trigger being pivoted from the first to the second trigger position, the braking pad is moved from the first to the second braking pad position.

Abstract: The present invention provides a method for positioning short circuit failure, used to position the short circuit point between a first metal wire and a second metal wire. The positioning method comprises: measuring the resistance between the first metal wire and the second metal wire, and positioning the first region where the short circuit point is located by a resistance ratio. In the first region, the short circuit point may be gradually approached by periodically cutting the first metal wire and the second metal wire, electrically isolating the cut portions, and performing a plurality of voltage contrast analysis on the first metal wire and the second metal wire based on the principle of the dichotomy, thereby accurately locating the short circuit point. With the positioning method provided by the present invention, the region where the short circuit defect of the nA (nano ampere) level is located may be accurately found from the first metal wire and the second metal wire that are extremely long.

Abstract: The disclosure relates to methods for determining imbibition of hydraulic fracturing fluids into hydrocarbon-bearing formations. More specifically, the disclosure relates to laboratory methods for determining certain unconventional flow parameters to measure the imbibition over time of hydraulic fracturing fluids into a low-permeability hydrocarbon-bearing rock formation.

Abstract: Methods and systems for removing near wellbore damage in a hydrocarbon reservoir are described. In one example implementation, an antenna is positioned inside a wellbore in a location corresponding to a formation where near wellbore damage occurs. The wellbore extends from a surface of a hydrocarbon reservoir downward into the subterranean structure of the hydrocarbon reservoir. An electromagnetic (EM) wave is transmitted to the antenna. A portion of the EM wave is irradiated at the formation. The portion of the EM wave removes the near wellbore damage at the formation.

Abstract: The present invention discloses a virtualized network function (VNF) failover method and apparatus, so as to resolve a problem that an affinity policy cannot be compatible with a high availability (HA) mechanism in a network functions virtualization (NFV) scenario. The method is: receiving, by a management and orchestration (MANO} system, a fault message, where the fault message indicates a first VNF is faulty; determining, by the MANO system, a primary affinity group to which the first VNF belongs and a secondary affinity group corresponding to the primary affinity group, where VNFs in the secondary affinity group are in a one-to-one correspondence with VNFs in the primary affinity group, and the affinity group represents a set of VNFs on which an affinity policy is used; and instructing, by the MANO system, the VNFs in the secondary affinity group to continue to process services of the VNFs in the primary affinity group.

Abstract: Nuclear magnetic resonance (NMR) well logs are obtained from a well in the reservoir measures of the total fluid, including both water and hydrocarbon, in the shale of the reservoir. NMR measurement at the surface of shale subsurface samples obtained in the form of drill cuttings or core samples from the same well provide measures of total water content of the shale. At the surface, pressure on the subsurface sample becomes that of atmospheric pressure, and hydrocarbon gas contained in the shale cuttings bleeds off. The remaining fluid within the shale cuttings is then only water, which can be measured using NMR techniques. Compensation for the effect of drilling fluids (drilling mud) on the NMR measures from the fluid cuttings is also performed. The hydrocarbon gas content of the formation shale can be determined from the difference between formation NMR well log readings and NMR measurements from subsurface sample.

Abstract: Nuclear magnetic resonance (NMR) well logs are obtained from a well in the reservoir measures of the total fluid, including both water and hydrocarbon, in the shale of the reservoir. NMR measurement at the surface of shale subsurface samples obtained in the form of drill cuttings or core samples from the same well provide measures of total water content of the shale. At the surface, pressure on the subsurface sample becomes that of atmospheric pressure, and hydrocarbon gas contained in the shale cuttings bleeds off. The remaining fluid within the shale cuttings is then only water, which can be measured using NMR techniques. Compensation for the effect of drilling fluids (drilling mud) on the NMR measures from the fluid cuttings is also performed. The hydrocarbon gas content of the formation shale can be determined from the difference between formation NMR well log readings and NMR measurements from subsurface sample.

Abstract: Nuclear magnetic resonance (NMR) well logs are obtained from a well in the reservoir measures of the total fluid, including both water and hydrocarbon, in the shale of the reservoir. NMR measurement at the surface of shale subsurface samples obtained in the form of drill cuttings or core samples from the same well provide measures of total water content of the shale. At the surface, pressure on the subsurface sample becomes that of atmospheric pressure, and hydrocarbon gas contained in the shale cuttings bleeds off. The remaining fluid within the shale cuttings is then only water, which can be measured using NMR techniques. Compensation for the effect of drilling fluids (drilling mud) on the NMR measures from the fluid cuttings is also performed. The hydrocarbon gas content of the formation shale can be determined from the difference between formation NMR well log readings and NMR measurements from subsurface sample.

Abstract: Techniques for determining geologic formation permeability include determining particular permeability values from an NMR log permeability data and particular permeability values of the core permeability measurements; determining a selected NMR permeability transform that includes inputs including the determined particular permeability values; minimizing a cost function to optimize the selected NMR permeability transform; calculating new permeability values for the wellbore between the terranean surface and a true vertical depth of the wellbore with the optimized NMR permeability transform; comparing the calculated new permeability values at particular depths between the terranean surface and the true vertical depth that match depths of the core permeability measurements; based on the comparison meeting a particular threshold, generating a user interface that renders one or more graphical representations of the optimized NMR permeability transform and the calculated new permeability values; and transmitting d

Abstract: The present invention relates to methods for analyzing and modeling natural gas flow in subterranean shale reservoirs. In preferred embodiments, methodologies and techniques for determining and modeling natural gas flow in shale formations using methodologies and techniques capable of determining natural gas properties related to dual-continuum flow, permeability and pressure within a subterranean shale reservoir. In some embodiments, the natural gas properties are determined by subjecting a subterranean shale reservoir sample to pulse-decay analysis. In certain embodiments, the methodologies and techniques described herein may be used in various reservoirs exhibiting macroporosity and/or microporosity, such as fractured reservoirs and carbonate reservoirs composed of reservoir fluids.

Abstract: Methods and systems for determining permeability, as a function of pore pressure, and porosity of a subsurface formation. The method includes positioning a sample in a sample assembly comprising of a gas and a pressure gauge, inside a pressure vessel comprising gas or liquid and a pressure gauge, measuring a first gas pressure, pi, of the sample inside the pressure vessel, applying a second gas pressure, po, to the pressure vessel, the second gas pressure being greater than the first gas pressure, measuring a third gas pressure, p, at time, t, at location, x, from the inlet of sample inside the pressure vessel, determining a total gas mass per unit volume of the subsurface formation, m, and determining the permeability, k, of the subsurface formation as a function of pore pressure based at least in part on the first gas pressure, the second pressure, the third gas pressure, and the gas density, with a single test run.

Abstract: Nuclear magnetic resonance (NMR) well logs are obtained from a well in the reservoir measures of the total fluid, including both water and hydrocarbon, in the shale of the reservoir. NMR measurement at the surface of shale subsurface samples obtained in from drill cuttings or core samples of the same well provide measures of total water content of the shale. At the surface, pressure on the subsurface sample becomes that of atmospheric pressure, and hydrocarbon gas contained in the shale cuttings bleeds off. The remaining fluid within the shale cuttings is then only water, which can be measured using NMR techniques. Compensation for the effect of drilling fluids (drilling mud) on the NMR measures from the fluid cuttings is also performed. The hydrocarbon gas content of the formation shale can be determined from the difference between formation NMR well log readings and NMR measurements from subsurface sample.

Abstract: The present disclosure describes methods and systems for fracturing geological formations in a hydrocarbon reservoir. One method includes forming a borehole in a hydrocarbon reservoir from a surface of the hydrocarbon reservoir extending downward into the hydrocarbon reservoir; transmitting an electromagnetic (EM) wave through the borehole: directing at least a portion of the EM wave to rocks at a location below the surface in the hydrocarbon reservoir; and fracturing the rocks at the location below the surface in the hydrocarbon reservoir by irradiating the rocks around the borehole using at least the portion of the EM wave, wherein irradiating the rocks elevates pore-water pressure in the rocks causing fracturing of the rocks.

Abstract: Disclosed are a network access method and a mobile communications terminal. The method comprises: determining a network standard supported by a mobile communications terminal; adding to an equivalent public land mobile network (EPLMN) the network identifier of a public land mobile network (PLMN) of the determined network standard supported by the mobile communications terminal; if a PLMN matching the network identifier of the EPLMN is discovered by searching, then establishing a communications connection between the mobile communications terminal and the matching PLMN.

Abstract: Systems and methods for analyzing and modeling natural gas flow in subterranean shale reservoirs. In some embodiments, methodologies and techniques for determining and modeling natural gas flow in shale formations using methodologies and techniques capable of determining natural gas properties related to dual-continuum flow, permeability, and pressure within a subterranean shale reservoir. In some embodiments, the natural gas properties are determined by subjecting a subterranean shale reservoir sample to pulse-decay analysis. In certain embodiments, the methodologies and techniques described may be used in various reservoirs exhibiting macroporosity and microporosity, such as fractured reservoirs and carbonate reservoirs composed of reservoir fluids.

Abstract: Methods and systems for detecting impact of induced micro-fractures in a subsurface formation are disclosed. The method includes determining an unloading effective stress (?ul) in a formation sample taken from a wellbore drilled into the subsurface formation, determining a fracture closure stress (?cl) of the formation sample, determining that the unloading effective stress (?ul) is greater than or equal to the fracture closure stress (?ul), and in response to determining that unloading effective stress (?ul) is greater than or equal to the fracture closure stress (?ul), operating the well system to inhibit impact of micro-fractures in the wellbore.

Abstract: Systems and methods for determining shear failure of a rock formation are disclosed. The method includes receiving, by a processor, a plurality of parameters related to physical properties of the rock formation, applying the plurality of parameters to a predetermined failure criterion, and determining shear failure of the rock formation based on the failure criterion. In some embodiments the failure criterion is a modified Hoek-Brown failure criterion that takes into consideration an intermediate principal stress, and the difference between normal stresses and an average confining stress.

Abstract: Provided are a method and an apparatus for identifying a pseudo base-station, and a terminal and the method includes the follows. A terminal is redirected to a target cell supporting circuit domain business when receiving a first call request in a first serving cell not supporting the circuit domain business. A location area update is sent a request to a base-station where the target cell is located when LAIs stored do not include a LAI of the target cell. The terminal determines that the base-station where the target cell is located as a pseudo base-station when no message responsive to the location area update request is received from the base-station where the target cell is located during the first preset time length and the interval at which the terminal conducts a location area update as indicated by the base-station where the target cell is located meets a preset condition.

Abstract: The present disclosure describes methods and systems for fracturing geological formations in a hydrocarbon reservoir. One method includes forming a borehole in a hydrocarbon reservoir from a surface of the hydrocarbon reservoir extending downward into the hydrocarbon reservoir; transmitting an electromagnetic (EM) wave through the borehole: directing at least a portion of the EM wave to rocks at a location below the surface in the hydrocarbon reservoir; and fracturing the rocks at the location below the surface in the hydrocarbon reservoir by irradiating the rocks around the borehole using at least the portion of the EM wave, wherein irradiating the rocks elevates pore-water pressure in the rocks causing fracturing of the rocks.

Abstract: A subterranean zone can be treated by introducing an acid-generating material and a proppant to the subterranean zone. Fractures are created in the subterranean zone using the acid-generating material. The proppant is positioned within the created fractures to keep the fractures open.