Abstract: Methods and systems for supply of fuel for a turbine-driven fracturing pump system used in hydraulic fracturing may be configured to identify when the supply pressure of primary fuel to a plurality of gas turbine engines of a plurality of hydraulic fracturing units falls below a set point, identify a gas turbine engine of the fleet of hydraulic fracturing units operating on primary fuel with highest amount of secondary fuel available, and to selectively transfer the gas turbine engine operating on primary fuel with the highest amount of secondary fuel from primary fuel operation to secondary fuel operation. Some methods and systems may be configured to transfer all gas turbine engines to secondary fuel operation and individually and/or sequentially restore operation to primary fuel operation and/or to manage primary fuel operation and/or secondary fuel operation for portions of the plurality of gas turbine engines.

Abstract: A method for quantifying frac hits within a few days using a novel pressure-transient analysis technique called differential pressure-transient analysis (DPTA). Unlike pressure transient analysis (PTA) methods, focused on single-well analyses, DPTA evaluates pressure response from two or more wells simultaneously to (1) determine the existence of frac hits, and (2) determine the magnitude of interference, defined as the ratio of inter-connected to total number of primary fractures from a given well. The output from (2) can be subsequently used to accurately predict oil and/or gas production rates for infill and offset wells.

Abstract: The present disclosure is for an inverted diffuser usable in wellheads and other wellsite equipment. The inverted diffuser includes at least one first section having a first vertical inner surface, a first inclined inner surface relative to the first vertical inner surface, and one or more channels supporting one or more releasable fasteners between the at least one first section and a wall of a wellhead or of a wellsite equipment. At least one second section is press-fitted or fastened adjacent to the at least one first section. A method for application of the inverted diffuser in a wellhead and in other wellsite equipment is also disclosed, along with a method of manufacture of the inverted diffuser.

Abstract: A method includes assembling a first tool string to include at least one original perforating gun and an original gun switch in communication with the original perforating charge, and inserting the first tool string into a first wellbore. The method also includes retrieving the first tool string from the first wellbore and recovering the original gun switch from the first tool string, assembling a new tool string to include at least one new perforating gun, wherein the new tool string further includes the recovered original gun switch whereby the original gun switch is in communication with the new perforating charge, and inserting the new tool string into at least one of the first wellbore and a different wellbore, and delivering a signal to the original gun switch to initiate detonation of the second perforating gun.

Abstract: A system has a fin with an upstream end, a downstream end, a wall interface (412), a carrier interface (414) offset from the wall interface (412) in a radially inward direction, and an impact surface (418). The impact surface extends between an upstream end of the wall interface and an upstream end of the carrier interface. The impact surface (418) has a substantially flat portion configured to cause flow stagnation. The fin (306) has a side surface (416) extending between the impact surface (418), the wall interface (412), and the carrier interface. The impact surface (418) is joined to the side surface (416) by an edge profile (420) configured to cause turbulence or separation of the fluid flow from the fin.

Abstract: A method includes locating a first set of electromagnetic field emitting devices in a vicinity of the pressure source, using the first set of electromagnetic field emitting devices to generate a first electromagnetic field in a first shape that forms an enclosure containing the pressure source, pumping a magnetic fluid into the enclosure at a pumping pressure, and increasing the pumping pressure to overcome the pressure from the pressure source.

Abstract: A system and method of testing diverting agents may include injecting a diverting agent into a testing device. The system may be configured to inject a diverting agent into a testing device configured to receive a fluid through a flow channel and, change the flow channel in a transverse direction relative to the direction of the fluid flow.

Abstract: The integration joint assembly includes an integration joint body (10) having a through bore (16), the body being for connection with a riser system. The integration joint assembly permits a tubular work string (50; 54) to pass there through such that there is an annulus created between the inner through bore (16) of the integration joint body (10) and the outer surface of the tubular work string (50; 54). The integration joint body (10) can also include at least two (300, 200) and more preferably three sealing devices (300, 200, 100) within its through bore (16). A method of drilling is also described as including the steps of installing an integration joint assembly in a riser string and running a tubular work string (50; 54) through the through bore (16) thereof.

Abstract: Methods and systems for determining a spectral ratio log using a time domain seismic image and a seismic velocity model are disclosed. The method includes determining a first mono-spectral seismic image and a second mono-spectral seismic image from the time domain seismic image. The method further includes determining a time domain spectral ratio image from the first mono-spectral seismic image and the second mono-spectral seismic image and transforming the time domain spectral ratio image into a depth domain spectral ratio image using the seismic velocity model. The method still further includes defining a wellbore path through the depth domain spectral ratio image and determining a spectral ratio log along the wellbore path from the depth domain spectral ratio.

Abstract: A hydraulic fracturing system is disclosed as including a singular mobile platform of at least one mobile power unit (MPU) and at least one first switch gear that is configured to handle electric power from the MPU. The MPU is configured to generate voltage that matches the requirements of an electrical bus from the at least one switch gear such that a combined electrical current generated as a result of the generated voltage is provided to the electrical bus to the components of the hydraulic fracturing system. Further, the hydraulic fracturing system may include electrical fracturing equipment with at least one second switch gear to support the at least one first switch gear in handling electric power from the MPU. A datavan may be included in the system to control load shedding, load sharing, and power distribution for the electrical fracturing equipment comprising the at least one second switch gear.

Abstract: A method may include monitoring, by a controller, operation of a pump of at least one hydraulic fracturing rig during ramp-up of the pump. Each of the at least one hydraulic fracturing rig may further include an engine and a transmission. The method may further include detecting, by the controller, an issue in the operation of the pump based on the monitoring of the operation and performing an action based on the detecting of the issue.

Abstract: Systems and methods are disclosed for managing skin in a subterranean wellbore. In an embodiment, the method includes oscillating a drawdown pressure of the subterranean wellbore in a predetermined pattern that comprises a plurality of alternating drawdown pressure increases and drawdown pressure decreases. The drawdown pressure increases of the predetermined pattern comprise increasing the drawdown pressure at a first rate, and the drawdown pressure decreases of the predetermined pattern comprise decreasing the drawdown pressure at a second rate that is different from the first rate.

Abstract: This disclosure presents processes for automatically detecting a ball-seat event in a wellbore. The processes can automatically detect a ball-seat event and automatically fracture a formation at a next treatment zone once the ball-seat event has been automatically detected. The processes for automatically detecting the ball-seat event can determine a volume ratio is in a predetermined range and within a minimum and maximum bound, then determine a slurry rate is in a predetermined range and is within a minimum and maximum bound, then determine a slope of a slurry rate is in a predetermined range and within a minimum and maximum bound, and then determine a slope of a pressure change of the fracturing fluid in the wellbore is in a predetermined range and within a minimum and maximum bound.

Abstract: A method of managing an influx encountered during a drilling operation conducted with respect to a wellbore includes drilling a wellbore into a subterranean formation. Drilling the wellbore includes circulating a drilling fluid through a wellbore while operating a drill bit and monitoring one or more parameters associated with the drilling operation for indicia of the influx within the wellbore. The method also includes, upon detecting the indicia of the influx, determining, via an influx management model, an initial influx volume.

Abstract: A method includes monitoring fluid production at a passive ICD installed in a base pipe in a wellbore. Responsive to monitored fluid production meeting one or more predetermined criteria, a remedial sleeve component is installed for the passive ICD. The remedial sleeve component includes: one or more ports which permit throughput of fluid into the base pipe; a closing portion which selectively opens and closes the one or more ports; and one or more sealing portions, which prevent a flow of fluid into the base pipe when the one or more ports are closed. The one or more ports are selectively opened or closed responsive to one or more additional predetermined criteria. A related system includes an actuation tool which deploys into the wellbore to actuate the closing portion to selectively open and close the one or more ports.

Abstract: Drilling installation comprising a cantilever with a drilling floor for performing drilling operations; further comprising an independent operations handling system arranged for handling equipment underneath the drilling floor independent of the drilling operations on the drilling floor, wherein the independent operations handling system comprises a handling element for cooperation with the equipment to be handled, wherein the handling element is extendible underneath the cantilever.

Abstract: A powertrain for powering wellsite pumping operations includes a power source for producing energy, a power bank, electric motors coupled to pumps, and a power management system. The power source can be a prime mover coupled to a generator, the prime mover sized for supply up to the average power demand of the pumping operation, and the power bank is sized to supply up to at least the difference between the peak and average power demand of the pumping operation, thereby providing a load levelling means to satisfy peak demand of the operation. The power management system manages the direction of current flow, state of charge of the power bank, and power source operation to provide least fuel consumption while meeting the power demand of the pumping operation.

Abstract: Techniques for determining a reservoir characteristic include determining, with an analytical solution, a change to at least one control point of a boundary of a control volume defined in a subterranean formation, the change to the at least one control point caused by a hydraulic fracture formed in or adjacent the subterranean formation; determining, with a numerical solution, a fluid pressure change of the control volume based on the change to the at least one control point; and determining, with a mechanical model based on the analytical solution and the numerical solution, at least one reservoir characteristic based at least in part on the determined fluid pressure change of the control volume.

Abstract: In a dart for a downhole device according to the present invention, a ball is formed of a first degradable material having a first degradation rate, a mandrel is formed of a second degradable material having a second degradation rate lower than the first degradation rate, and a sleeve is formed of the second degradable material or a third degradable material having a third degradation rate lower than the second degradation rate.

Abstract: There are provided high power laser perforating tools and methods of delivering laser energy patterns that enhance the flow of energy sources, such as hydrocarbons, from a formation into a production tubing or collection system. These tools and methods precisely deliver predetermined laser beam energy patterns, to provide for custom geometries in a formation. The patterns and geometries are tailored and customized to the particular geological and structural features of a formation and reservoir.