Abstract: Apparatus includes a conveyance device and a first shearable deployment bar connected to the conveyance device at a first distal end of the first shearable deployment bar, where the first shearable deployment bar has a deployment bar section and a shearable section. The shearable deployment bar is configured to carry a ballistic signal from an initiating charge, through the shearable deployment bar, and to a donor charge. The apparatus further includes a first set of perforating guns connected to the first shearable deployment bar at a second distal end thereof, and the first set of perforating guns are configured to receive the ballistic signal from the donor charge to ultimately fire the perforating guns at a targeted location in a wellbore. A second shearable deployment bar may be connected to the first set of perforating guns, and a second set of perforating guns connected to the second shearable deployment bar.

Abstract: Apparatus and methods for pressurizing well operations fluids via a pressure exchanger having a housing with a bore extending between first and second ends of the housing and a rotor rotatably disposed within the bore of the housing. A chamber extends through the rotor between first and second ends of the rotor. The chamber has a larger chamber diameter section and a smaller chamber diameter section. A piston assembly is slidably disposed within the chamber. The piston assembly has a larger piston diameter section slidably disposed within the larger chamber diameter section and a smaller piston diameter section slidably disposed within the smaller chamber diameter section.

Abstract: A technique facilitates a fracturing operation in a borehole and surrounding formation. The technique utilizes braking to arrest the rotation of an electric frac system and to thus limit the magnitude of a pressure peak in the event of an over-pressure shut down or other type of emergency shutdown. According to an embodiment, an electric motor is coupled with a fracturing pump which may be operated to pump a fracturing fluid into a well. Stopping or otherwise braking of the electric frac system is facilitated by applying rotor drag to a rotor of the electric motor.

Abstract: A fluid manifold segment operable for detachably coupling with another instance of the fluid manifold segment to form a fluid manifold assembly. The fluid manifold segment may include a plurality of pressure exchangers each having a clean fluid inlet a clean fluid outlet, a dirty fluid inlet, and a dirty fluid outlet. The fluid manifold segment may further include a first fluid conduit having opposing end ports and intermediate ports, a second fluid conduit having opposing end ports and intermediate ports each fluidly connected with the clean fluid outlet of a corresponding pressure exchanger, a third fluid conduit having opposing end ports and intermediate ports each fluidly connected with the dirty fluid inlet of a corresponding pressure exchanger, and a fourth fluid conduit having opposing end ports and intermediate ports each fluidly connected with the dirty fluid outlet of a corresponding pressure exchanger.

Abstract: A technique facilitates startup power and/or reserve power at an electric frac wellsite. An energy storage system, e.g. a battery bank, may be coupled with corresponding equipment and mounted on a transport for delivery to a desired wellsite. Additionally, the energy storage system may be coupled with a transformer which may be mounted on the same or a different trailer or skid. The energy storage system is configured to provide sufficient power for enabling turbine generator start up and/or provision of reserve power for other wellsite activities. In some embodiments, the energy storage system may be used to provide reserve power useful for improving operation of electric fracturing systems and for reducing the risk of wellsite shut down and cleanout.

Abstract: Apparatus and methods for pressurizing well operations fluids. An example apparatus may include a plurality of pressure exchangers each operable to receive a first fluid via a low-pressure inlet, receive a second fluid via a high-pressure inlet to thereby pressurize and then discharge the first fluid via a high-pressure outlet, and discharge the clean fluid via a low-pressure outlet. The apparatus may further include a fluid control device fluidly connected with the pressure exchangers downstream from the low-pressure outlets. The fluid control device may be a pump operable to draw the clean fluid discharged via the low-pressure outlets and thereby reduce the pressure at the low-pressure outlets and the low-pressure inlets.

Abstract: Apparatus and methods for utilizing pressure exchangers as a source of pressure oscillations. An example method includes operating a plurality of pressure exchangers to pressurize a stream of fluid, injecting the pressurized stream of fluid into a wellbore extending into a subterranean formation, and controlling rotational speed and rotational position of a rotor of each of the pressure exchangers to control amplitude and/or frequency of pressure oscillations within the pressurized stream of fluid being injected into the wellbore.

Abstract: Methods include deploying a downhole tool into a wellbore with a conveyance apparatus by mounting a tool to a distal end of a spooled conveyance apparatus, routing the conveyance apparatus around a powered sheave assembly, which includes a plurality of grooves disposed on the outer surface of the sheave to accommodate the conveyance apparatus, and providing a power source for applying torque to the powered sheave. The powered sheave assembly then deploys the conveyance apparatus into the wellbore. In some cases a traction device may be disposed between the powered sheave and the wellbore to provide axial force in both directions. The conveyance apparatus is moved through a sealing apparatus, a blowout preventer, and a wellhead, with the powered sheave, after the routing the conveyance apparatus around a powered sheave.

Abstract: Systems and techniques for locating a tool component in a channel of a blowout preventer. The system and technique may include the use of glide rams that are configured to sealably engage a deployment bar of a toolstring supporting the tool component in the channel. The glide rams may allow for movement of the deployment bar and toolstring while maintaining the seal. Due to greater diameter of the tool component, contact with the rams may be detected in the form of a spike in load detected at an oilfield surface by equipment supporting the conveyance means for the toolstring. Thus, tool component location may be ascertained. This same diameter difference of the tool component may also be utilized to deflect a member in the channel for sake of tool location.

Abstract: A system and technique for locating a tool in a channel of a blowout preventer. The system and technique may include the use of a tool locating device that includes flappers to detect tool components of a toolstring for a well application. The toolstring is segmented with deployment bars and tool components of differing diameters. For example, the deployment bars may be of a diameter that substantially matches that of an associated conveyance such as coiled tubing whereas the tool components may be of larger detectable diameters by the flappers. Once more, the flappers may also serve a centralization function as the conveyance is run through the blowout preventer.

Abstract: Methods include providing a blowout preventer body having at least one sealing ram for engaging with a downhole tool, and the sealing ram is hydraulically actuatable between a ram open position and a ram closed position. A hydraulic control valve is provided and used for sensing a differential pressure across the at least one sealing ram. The hydraulic control valve is fluidly connected to the blowout preventer body, and the hydraulic control valve operates as a hydraulic interlock to prevent the at least one sealing ram from being moved to the ram open position under predetermined differential pressure conditions. The blowout pre-venter is connected to a wellhead disposed on a wellbore, and the downhole tool and coiled tubing are deployed into and out of the wellbore.

Abstract: A pressure wave system having a tubular member, a signal source, a sensor, and a source of noise, has a noise interference system employing one or more a lateral branches to cancel pressure noise, and/or amplify or filter the pressure wave signal. A related method generates the pressure wave signal, connects the lateral branch or branches to amplify or filter the signal and/or cancel noise from the system, and receives the signal or a response of the system to the signal. The lateral branches are simple pipe stubs or loops that can be made using ordinary piping components, or are more complex designs.

Abstract: Apparatus for deploying coiled tubing into a wellbore include a neck portion extending between end connections, where the end connections are configured to be attached to a coiled tubing tool string, and a main flow passage, at least one secondary flow passage and at least one electrical device passageway extending through the neck portion and the end connections. A wireline cable or an optical fiber is disposed in the electrical device passageway, and a well treatment fluid flows through the main flow passage. The main flow passage may have a substantially circular cross sectional shape. The apparatus includes at least one secondary flow passage having a substantially circular cross sectional shape, which may be a tube disposed within the main flow passage. The electrical device passageway may in some cases be a tube disposed within the main flow passage.

Abstract: Apparatus and methods for utilizing pressure exchangers as a source of pressure oscillations. An example method includes operating a plurality of pressure exchangers to pressurize a stream of fluid, injecting the pressurized stream of fluid into a wellbore extending into a sub-terranean formation, and controlling rotational speed and rotational position of a rotor of each of the pressure exchangers to control amplitude and/or frequency of pressure oscillations within the pressurized stream of fluid being injected into the wellbore.

Abstract: Apparatus and methods for pressurizing well operations fluids. An example apparatus may include a plurality of pressure exchangers each operable to receive a first fluid via a low-pressure inlet, receive a second fluid via a high-pressure inlet to thereby pressurize and then discharge the first fluid via a high-pressure outlet, and discharge the clean fluid via a low-pressure outlet. The apparatus may further include a fluid control device fluidly connected with the pressure exchangers downstream from the low-pressure outlets. The fluid control device may be a pump operable to draw the clean fluid discharged via the low-pressure outlets and thereby reduce the pressure at the low-pressure outlets and the low-pressure inlets.

Abstract: Methods include providing a first portion of a tool string including a tool, a deployment bar, and at least one deployment valve, where the deployment valve includes a valve therein which is operable under wellbore pressure and further comprises a fluid passageway there through. The first portion of the tool string is connected to a conveyance device in a riser, and then moved into a blowout preventer body having at least one sealing ram for engaging with a neck on the deployment bar, where the valve is in an open position and the riser is under wellbore pressure during the moving. The at least one sealing ram is closed on the neck, valve closed, and pressure reduced in the riser. In some cases, the valve is pressure tested before pressure is reduced in the riser.

Abstract: Methods for deploying a coiled tubing string into a wellbore include providing a coiled tubing having a distal end and an opposing end connected with a reel, providing a tool including a tool body, a valve operable under wellbore pressure disposed within the tool body, and a first fluid passageway and a second fluid passageway defined within the tool body. Fluid communication is established through the distal end of the coiled tubing and the first fluid passageway and the second fluid passageway, and the coiled tubing and tool are deployed into the wellbore.

Abstract: A connector system includes a first sub and a second sub having a landing shoulder, and the first sub carries a threaded sleeve for engaging the second sub. The first sub includes a stinger section and a flying nut that provides a sealed and torque carrying connection when secured against the landing shoulder of the second sub. The first sub may be connected to the second sub without rotation of the ends of the first sub and the second sub. In some cases the first sub and the second sub are in any angular orientation when the sealed and torque carrying connection is provided. Further, the connector system may provide a connection between two sections of a downhole tool assembly without rotating or orienting in any way the angular position of the two sections. In some cases, torque applied in a wellbore milling operation further seals the sealed joint.

Abstract: Apparatus and methods for reducing pressure exchanger manifold resonance. Example apparatus include a first manifold and pumps fluidly connected with the first manifold. Each pump is operable to inject a pressurized clean fluid into the first manifold. The apparatus may further include a second manifold and pressure exchangers each fluidly connected with the first and second manifolds. Each pressure exchanger is operable to receive the pressurized clean fluid from the first manifold and discharge the pressurized dirty fluid into the second manifold. The apparatus may also include a first flow restricting orifice fluidly connected along the first manifold, a second flow restricting orifice fluidly connected along the second manifold, and a discharge conduit fluidly connected with the wellbore to permit the pressurized dirty fluid to be injected into the wellbore during a well treatment operation.

Abstract: Apparatus and methods for pressurizing well operations fluids via a pressure exchanger. The pressure exchanger has a housing, a rotor within the housing, a first cap covering the rotor at a first end of the housing, and a second cap covering the rotor at a second end of the housing. The rotor includes chambers distributed around a central axis of the rotor and a first fluid passage. Each of the chambers and the first fluid passage extend through the rotor between a first face of the rotor and a second face of the rotor. The first cap includes a first fluid inlet, a first fluid outlet, and a second fluid passage, and the second cap includes a second fluid inlet and a second fluid outlet. The second fluid passage fluidly connects the first fluid passage with the first fluid outlet.