Abstract: Apparatus and method for performing split stream operations with pressure exchangers. An example method may include operating a mixer to form a stream of concentrated dirty fluid, operating a first pump to form a pressurized stream of first clean fluid, operating a second pump to form a pressurized stream of second clean fluid, and transferring the pressurized stream of first clean fluid and the stream of concentrated dirty fluid through a plurality of pressure exchangers to pressurize the stream of concentrated dirty fluid.

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 removal of heat. The technique involves moving a process fluid through a buffer tank which is combined with a heat exchange system. The heat exchange system includes a conduit carrying a coolant fluid which removes excess heat from a heat source. The conduit is routed to the buffer tank so that the cooler process fluid moving through the buffer tank is able to remove heat from the coolant fluid before it is routed back to the heat source for continued heat removal. In a well application, for example, a heat source, e.g. an electric motor, may be located on a transport vehicle and cooled by the coolant fluid. The heat transferred to the coolant fluid from the heat source is removed by routing the coolant fluid through the conduit associated with the buffer tank. This enables the cooler process fluid in the buffer tank to be used in lowering the temperature of the coolant fluid.

Abstract: An apparatus having a plurality of pressure exchangers. Each pressure exchanger includes a first conduit and a second conduit and is operable for pressurizing a low-pressure dirty fluid via a high-pressure clean fluid. Each first conduit conveys the high-pressure clean fluid into a corresponding one of the pressure exchangers and to an adjacent one of the pressure exchangers, and each second conduit conveys a pressurized dirty fluid out of a corresponding one of the pressure exchangers and from the adjacent one of the pressure exchangers. The first conduits collectively form at least a portion of a high-pressure clean fluid manifold distributing the high-pressure clean fluid among the pressure exchangers, and the second conduits collectively form at least a portion of a pressurized dirty fluid manifold combining pressurized dirty fluid collectively discharged from the pressure exchangers.

Abstract: Apparatus include 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: A mixer sensing assembly of a mixer for mixing a wellsite fluid in a tank at a wellsite is provided. The mixer includes a shaft driven by a driver and a paddle operatively connectable to the shaft and rotatable therewith. The sensor assembly includes a mount operatively connectable to the shaft, a fluid interface, and a mixing sensor. The fluid interface is responsive to flow of the wellsite fluid passing thereby, and is connectable to the mount. The mixing sensor is connectable to the mount, the fluid interface, and/or the shaft to measure a strain applied to the thereto whereby fluid parameters of the wellsite fluid may be determined. The wellsite fluid may be mixed moving the components in the tank with the mixer, and measuring a strain on the mixer by detecting movement of the sensor assembly.

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: A method moves a tube wave reflector in a well, generates a tube wave, receives a reflection, and determines the depth of one or more reflector locations from the elapsed time. Also, a method to locate a feature in a well deploys a bottom hole assembly (BHA), generates acoustic noise from the BHA, and autocorrelates to determine the BHA depth. Also, a system has a coiled tubing string to a BHA, a surface wave generator, a surface and/or distributed receiver, and a recorder to determine elapsed times between generation and receipt.

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: A predetermined condition in a fluid-filled wellbore system can be detected by generating at least one sound in the wellbore system in response to the condition, such that a detectable change is created in some characteristic of the emitted sound, and detecting the at least one sound and the change, the detection being indicative that the predetermined condition has occurred. Equipment for facilitating detection of the condition can include a trigger operable in response to the condition; a generator operable to emit sound in the borehole and to create a detectable change in some characteristic of the emitted sound in response to the trigger; and at least one sensor operable to monitor the sound and detect the change, the detection being indicative that the predetermined condition has occurred. It is also possible to estimate a value of a property of a fluid-filled wellbore system.

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: 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: 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: 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. In some aspects, 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. In some aspects, 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: 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 preventer 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 method to generate a tube wave in a tubular system involves reciprocating a plunger in a chamber system to alternatingly increase and decrease net volume, drawing fluid from and returning the fluid to a tubular system and into and from the chamber system, to generate a tube wave, and guiding the tube wave to the tubular system. Also, a tube wave generator-sensor system has a chamber system, a plunger, a driver to reciprocate the plunger within the chamber system to generate a tube wave, a flow passage to guide the tube wave into a tubular system, and a sensor to receive the tube wave signal and/or response from the tubular system. The method and system can work with or without a firing valve and or accumulator, without adding or subtracting fluid from the tubular system.

Abstract: Apparatus and methods for performing subsea drilling operations. An example method may include receiving drilling fluid from a drilling fluid source at a first pressure by a pressure exchanger located within a subsea environment and receiving seawater from the subsea environment at a second pressure by the pressure exchanger to increase pressure of the drilling fluid within the pressure exchanger to a third pressure. The second and third pressures are substantially greater than the first pressure. The method may further include discharging the drilling fluid from the pressure exchanger into piping to communicate the drilling fluid to a drill forming a wellbore in a seabed and discharging the seawater from the pressure exchanger into the subsea environment.

Abstract: A method moves a tube wave reflector in a well, generates a tube wave, receives a reflection, and determines the depth of one or more reflector locations from the elapsed time. Also, a method to locate a feature in a well deploys a bottom hole assembly (BHA), generates acoustic noise from the BHA, and autocorrelates to determine the BHA depth. Also, a system has a coiled tubing string to a BHA, a surface wave generator, a surface and/or distributed receiver, and a recorder to determine elapsed times between generation and receipt.

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: An apparatus and method are disclosed for measuring a rheology indicator in a rheometer utilizing a rheometer attachment including a shaft having a shaft axis, an outer surface, and a plurality of helical vanes each extending radially from the outer surface.