A device and a method for gas-water-sand separation and measurement during a simulated exploitation of natural gas hydrates are disclosed. The device includes a natural gas hydrate formation and dissociation system and a filtering unit. The natural gas hydrate formation and dissociation system includes a compressed air pump, a reactor, and a water-bath temperature regulating unit. The filtering unit includes a kettle body, wherein an inlet end of the kettle body is connected to the sand-control liner zone, an outlet end of the kettle body is connected to a water-collecting container, and a plurality of filtering layers are disposed inside the kettle body from the inlet end to the outlet end. The method is conducted using the device. The device and the method realize the gas-water-sand separation and measurement of produced gas-water-sand mixture during a simulative exploitation process, allowing for a direct inspection on a sand production and sand control.

In one example, a method of designing a drill bit comprises obtaining a baseline orientation of a shaped cutter with respect to a bit body. The shaped cutter includes a shaped cutting element secured to a substrate. The baseline orientation is defined, at least in part, with respect to an rotational position of the shaped cutting element about a longitudinal axis of the shaped cutter. A wear imbalance is determined between opposing portions of the shaped cutting element at the baseline orientation. An adjusted orientation of the shaped cutter is generated having a different rotational position of the shaped cutting element about the cutter axis expected to reduce the wear imbalance.

A method for coupling hydraulic fracture network extension and production performance of a horizontal well in an unconventional oil and gas reservoir includes: establishing a complex hydraulic fracture network model of a fractured horizontal well in an unconventional oil and gas reservoir based on a fracture extension theory; constructing three-dimensional three-phase mathematical models of seepage for the fractured horizontal well based on an embedded discrete fracture model; and constructing a fully implicit numerical calculation model by a finite difference method through three-dimensional orthogonal grids, and solving iteratively, thereby accurately predicting a production performance characteristic of the fractured horizontal well in the unconventional oil and gas reservoir. The method combines a fracture extension model with a production performance prediction model to realize the coupled simulation and prediction of the hydraulic fracture network extension and production performance of the horizontal well in the unconventional oil and gas reservoir.

A drilling control system may access a drilling plan for a borehole comprising one or more of planned path for the borehole, drill string information, mud properties, drill bit properties, formation properties, and drill rig properties. The system may receive a plurality of operating parameters from a rig for the borehole including one or more of an observed toolface, a spindle setting, a rate of penetration, a differential pressure, and a weight-on-bit. The system may receive one or more propagation functions for the borehole determined by a model of the drill string. The system may determine one or more spindle changes or block speed changes based at least in part on the propagation functions and the plurality of operating parameters. The system may generate one or more predicted drill properties from a simulator using the one or more spindle changes or the one or more block speed changes.

Systems, methods, and computer-readable media that improve flow of a multiphase mixture in a fluid transport system by determining pressure drop of low-liquid loading flows are provided. The method includes obtaining physical dimensions of a pipe that transports a multiphase flow. The method also includes obtaining physical parameters of the multiphase flow in the pipe. The method further includes determining an effective toughness of a liquid film of the multiphase flow on an interior wall of the pipe using the physical dimensions of the pipe and the physical parameters of the multiphase flow. Additionally, the method includes determining a pressure drop in the pipe using the effective roughness of the liquid film. Moreover, the method includes determining operating parameters of the system based on the pressure drop in the pipe.

An apparatus to test a drilling fluid in a laboratory includes a test cell configured to test the fluid to determine a Sag Factor of the fluid. The test cell may be heated with a heating jacket to a predefined temperature. A plurality of densitometers are configured to continuously measure a density of the fluid circulating in the test cell. A computing device processes the density measurements to determine a Sag Factor of the drilling fluid.

Systems and methods include a computer-implemented method for determining an integrated surface-downhole integrity score for a natural flow oil well. Wellness surface parameters of a natural flow oil well are determined. Wellness downhole parameters for the natural flow oil well are determined, including parameters indicating well integrity and tubing/casing conditions. An integrated surface-downhole integrity score is determined using the wellness surface parameters and the wellness downhole parameters. An alert is provided for presentation to an operator in a user interface. The alert is provided in response to the integrated surface-downhole integrity score exceeding a threshold.

Systems and methods include a computer-implemented method for optimizing well drilling operations. An estimate for a maximum safe rate of penetration (ROP) is determined based on cutting concentrations in annulus (CCA) values. Hydraulics of mud pump+bit and jet impact force hydraulics are evaluated. A developed hole cleaning index is determined based on a carrying capacity model considering chemical and physical influences of drilling fluid rheology. A real-time Drilling Specific Energy (DSE) is determined using the estimate for the maximum safe ROP, the evaluated hydraulics, and the developed hole cleaning index. Optimal drilling parameters are determined using particle swarm optimization (PSO) and a penalty approach (PA). Optimal mechanical drilling parameters are determined using the optimal drilling parameters and by evaluating the real-time DSE. The optimal mechanical drilling parameters are used during drilling. The real-time developed DSE is correlated with fuel consumption to assess CO.sub.2 and toxics gases emission.

A method includes imaging, at an imaging resolution, a core of a subsurface formation to create a core image and iteratively performing the following operations until a defined feature of a rock of the subsurface formation exceeds a viewable image feature threshold: extracting a number of subsamples from the core for a first iteration and from each of the number of subsamples previously extracted for a subsequent iteration; increasing the imaging resolution; and imaging each subsample. The method includes performing the following operations for the subsamples last extracted: determining at least one formation property characteristic; determining a guiding rock property for each voxel of the core image and the number of subsample images; and determining a subsample that is a shortest distance to the voxel based on the number of guiding rock properties; and mapping, for each voxel, the at least one formation property characteristic that is the shortest distance.

Overlapping pores in a multiscale model of heterogeneous core formation contributes errors during flow simulations. A scale-coupled multiscale modeling that corrects for contributions of overlapping pores may be used to determine capillary pressure and relative permeability of the heterogenous core formation more accurately. The effects of overlapping pores may be removed by converting pores that have a certain radius or are filled with certain fluids into solid regions. The effects of overlapping pores may also be removed by running flow simulations on a modified model and correcting various fluid properties of the core formation with the results.