Methods, systems, and devices to enhance fracturing fluid delivery to subsurface formations to enhance hydrocarbon production from the subsurface formations may include providing a manifold coupling having a manifold coupling passage with a manifold coupling axis. The manifold coupling may include a first inlet passage positioned to provide fluid flow between a first fracturing fluid output and the manifold coupling passage, and a second inlet passage positioned opposite the first inlet passage to provide fluid flow between a second fracturing fluid output and the manifold coupling passage. The first inlet passage may have a first inlet passage cross-section at least partially defining a first inlet axis extending transverse relative to the manifold coupling axis. The second inlet passage may have a second inlet passage cross-section at least partially defining a second inlet axis extending transverse relative to the manifold coupling axis and not being co-linear with the first inlet axis.

Systems and methods for this disclosure describe systems and methods that are directed to monitoring active clay in water-based drilling fluid may be provided. A method for monitoring active clay concentration while drilling may be provided. The method may include providing a sample of water-based drilling fluid. The method may further include adding methylene blue to the sample in a methylene blue titration. The method may further include performing an impedance measurement on the sample during the methylene blue titration. The method may further include determining an endpoint of the methylene blue titration using a phase angle measurement from the impedance measurement. The method may further include correlating the endpoint to the active clay concentration of the sample. The method may further include determining a treatment for the water-based drilling fluid based on the active clay concentration.

Methods, systems, and devices to enhance fracturing fluid delivery to subsurface formations to enhance hydrocarbon production from the subsurface formations may include providing a manifold coupling having a manifold coupling passage with a manifold coupling axis. The manifold coupling may include a first inlet passage positioned to provide fluid flow between a first fracturing fluid output and the manifold coupling passage, and a second inlet passage positioned opposite the first inlet passage to provide fluid flow between a second fracturing fluid output and the manifold coupling passage. The first inlet passage may have a first inlet passage cross-section at least partially defining a first inlet axis extending transverse relative to the manifold coupling axis. The second inlet passage may have a second inlet passage cross-section at least partially defining a second inlet axis extending transverse relative to the manifold coupling axis and not being co-linear with the first inlet axis.

Systems and methods are described herein. The method generally includes generating frequency responses of one or more sample fluids having known fluid properties, selecting an equivalent circuit model for modeling the frequency responses, the equivalent circuit model including one or more model elements, calculating an equivalent impedance of the equivalent circuit model, generating a correlation between the one or more model elements and the known fluid properties, measuring an impedance of a drilling fluid, and determining at least one property of the drilling fluid based on the correlation between the one or more model elements and the known fluid properties.

An automated batch sampling drilling mud management system (1) includes a portable mud measurement system (10) and a communications system (120). The portable mud measurement system (10) has one or more measurement devices (14) arranged to measure at least one property and/or characteristic of drilling mud; and a pumping system (16) arranged to pump a batch sample of drilling mud from a supply of drilling mud to the one or more measurement devices. The pumping system (16) is also able to subsequently flush the batch sample of drilling mud from the one or more measurement devices (14). The communications system (120) enables bidirectional communications between the mud management system (10) and a remote location to enable transfer of data therebetween and the exertion of control from the remote location to the mud management system (10).

Systems and methods for conveying non-dry frac proppant are described herein. The system generally includes at least one hopper having at least one moisture sensor, a slide gate that is fluidly connected to the at least one hopper, a conveyor assembly having at least one conveyor belt configured to convey the non-dry frac proppant from the at least one hopper to a blender, and at least one load sensor, and a control device configured to regulate a discharge rate of the non-dry frac proppant and a load rate of the non-dry frac proppant. The method generally includes providing the system at a well site to convey a non-dry frac proppant from a source point the at least one hopper, the conveyor assembly at a discharge rate determined by the control device, and the blender at a load rate determined by the control device.

Systems and methods measure one or more rheological properties and/or parameters of a fluid and establish at least one correlation between the measured one or more rheological properties and/or parameters. The systems and methods may correlate the measured one or more rheological properties and/or parameters to static aging results to establish the at least one correlation between the one or more rheological properties and/or parameters of the fluid. The systems and methods may predict at least one sagging tendency of the fluid based on the established at least one correlation and may measure and/or monitor static sagging of the fluid based on the predicted at least one sagging tendency of the fluid. The systems and methods may guide fluid treatment of the fluid or produce a mud system based on the predicted at least one sagging tendency of the fluid.

Control of a drilling system drilling a wellbore is improved using a hydraulic model corrected for pressure losses. A surface backpressure of the outlet and a standpipe pressure of the inlet are measured with sensors in the system. An estimate of the standpipe pressure is calculated based integrating from the measured surface backpressure back to the inlet in the hydraulics model. The pressure loss increment in the hydraulics model is calculated based on a difference between the measured and estimated standpipe pressures. Meanwhile, a parameter in the drilling system is monitored during drilling so the parameter can be adjusted at least partially based on the hydraulics model corrected for the pressure loss.

Methods and compositions for using shale inhibitor additives in subterranean formations, and specifically, to dried shale inhibitor additives and methods for use are provided. In one embodiment, the methods include providing a dried shale inhibitor additive that includes a precipitate of at least one liquid amine shale inhibitor; allowing at least a portion of the dried shale inhibitor additive to dissolve in a treatment fluid including an aqueous base fluid; and introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation.

An automated drilling-fluid additive system and method for on-site real-time analysis and additive treatment of drilling fluid to be injected into a well. The drilling fluid includes returned drilling fluid intended to be re-used, which has a variety of viscosity and other qualities resulting from its various preceding use. The target drilling fluid will have a variety of viscosity and other qualities depending upon and changing with various phases of drilling operations and various conditions encountered. The drilling fluid is analyzed in real time as it flows into the automated drilling-fluid additive system, and various additives are added to and thoroughly blended with the drilling fluid as needed to achieve the desired result. The blended drilling fluid is discharged from the automated drilling-fluid additive system in the proper condition for injection into a well.