Abstract: A downhole casing cutting and removal assembly (10) and method of use thereof, the assembly comprising a work string (23) with a cutting mechanism (18) and plurality of resettable anchor mechanisms (20B-20D). The arrangement allows a test pull to be made following the cut by an anchor mechanism closer to the upper end of the cut casing section than an anchor mechanism (20B-20D) located close to the cutting mechanism. Time is thus saved by not having to raise and lower a single anchor mechanism (20B-20D) between the cutting position and the upper end of the cut casing section to undertake a test pull.

Abstract: A device for transferring torque to a drill bit in a borehole having a borehole axis includes a support element configured to rotate in the borehole about the borehole axis, a torque transferring element configured to transfer torque from the support element to the drill bit and further configured to isolate torsional oscillations that are created at the drill bit from the support element, a blocking element configured to block rotation of the torque transferring element relative to the support element about the borehole axis in at least one direction, and a bearing element between the support element and the drill bit.

Abstract: Downhole electrical energy harvesting and communication in systems for well installations having metallic structure carrying electric current, for example CP current. In some instances there is a harvesting module (4) electrically connected to the metallic structure (2) at a first location and to a second location spaced from the first location, the first and second locations being chosen such that, in use, there is a potential difference therebetween due to the electric current flowing in the structure (2); and the harvesting module (4) being arranged to harvest electrical energy from the electric current. In addition or alternatively, there may be communication apparatus (4, 5, 6) for communication by modulation of the current, for example CP current, in the metallic structure (2).

Abstract: Methods and systems for damping torsional oscillations of downhole systems are described. The systems include a downhole string, a bit support assembly configured to support and receive a disintegration device, wherein the disintegration device is disposed on an end of the downhole string and mounted to the bit support assembly, and a damping system configured at least one of on and in the bit support assembly, the damping system comprising at least one damper element arranged in contact with a portion of the bit support assembly.

Abstract: 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.

Abstract: A method of formation fluid sampling that includes setting a dual packer tool in a wellbore. The dual packer tool is used to isolate an interval between an upper packer and a lower packer. The method also includes drawing fluid from the interval with a lower inlet, until an oil fraction increases over a base line reading, and drawing oil from by pumping at a low rate with an upper inlet.

Abstract: 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.

Abstract: A method of hydraulic fracturing of an oil producing formation includes the provision of a heating apparatus which is transportable and that has a vessel for containing water. A water stream of cool or cold water is transmitted from a source to a mixer, the cool or cold water stream being at ambient temperature. The mixer has an inlet that receives cool or cold water from the source and an outlet that enables a discharge of a mix of cool or cold water and the hot water. After mixing in the mixer, the water assumes a temperature that is suitable for mixing with chemicals that are used in the fracturing process, such as a temperature of about 40°-120° F.+ (4.4-48.9 C+). An outlet discharges a mix of the cool or cold and hot water to surge tanks or to mixing tanks. In the mixing tanks, a proppant and an optional selected chemical or chemicals are added to the water which has been warmed.

Abstract: An array of sensors provided on the outside of a tubular string for measuring a property within the tubular string. The array of sensors may include a plurality of connected sensors, wherein at least one of the plurality of connected sensors is at least partially encompassed in a shroud. A snorkel line may extend from the shroud, the snorkel line capable of coupling with a sensor port in a tubular of the tubular string. The snorkel line may establish fluid communication between one of the sensors at least partially encompassed in the shroud and a corresponding sensor port of a tubular in the tubular string.

Abstract: A downhole motor for directional drilling includes a driveshaft assembly including a driveshaft housing and a driveshaft rotatably disposed within the driveshaft housing, a bearing assembly including a bearing housing and a bearing mandrel rotatably disposed within the bearing housing, wherein the bearing mandrel is configured to couple with a drill bit, a bend adjustment assembly configured to adjust a bend setting of the downhole motor, and an electronics package coupled to the driveshaft assembly, wherein the electronics package is configured to receive data from sensors of the downhole motor.

Abstract: A method of freeing a stuck pipe includes positioning a pipe freeing tool within the wellbore at a location proximate the stuck pipe, the pipe freeing tool including a downhole conveyance; and an arm coupled to the downhole conveyance, and activating the arm of the pipe freeing tool to apply a force to an external surface of the stuck pipe, wherein the force moves the stuck pipe away from a surface of the wellbore and towards a center of the wellbore. Another method of freeing a stuck pipe from a wellbore includes positioning a pipe freeing tool within the wellbore at a location proximate the stuck pipe, the pipe freeing tool including a jack device and a set of wheels coupled to the jack device, and activating the jack device of the pipe freeing tool to apply a force to an external surface of the stuck pipe.

Abstract: An assist device for propelling a tool through a conduit, the assist device including an upstream housing having a first port; a downstream housing movably attached to the upstream housing and the downstream housing having a second port; and a swab element attached to the downstream housing. The first port is closed when there is no gap between the upstream housing and the downstream housing, and the first port is open when there is a gap between the upstream housing and the downstream housing.

Abstract: A snubbing jack including a jack assembly including a base plate, a traveling plate, an axis extending through the base plate and the traveling plate, and a plurality of piston-cylinder assemblies, a rotary drive including a rotary base and a hub, wherein the rotary drive is configured to rotate the hub relative to the rotary base, a clamp coupled to the rotary base and configured to grip a first tubular member, a power tongs coupled to the rotary base and configured to grip a second tubular member and to rotate the second tubular relative to the rotary base, and a torque transfer device coupled between the rotary drive and the jack assembly and configured to allow the rotary drive to move axially relative to the base plate and configured to restrict rotation of the rotary drive relative to the jack assembly.

Abstract: A plug release system includes a tubular member having an outer surface and an inner surface defining a flow bore having a central longitudinal axis. A sleeve is positioned in the flow bore. The sleeve includes a first end having a radially outwardly extending annular lip, and a second end. A release mechanism is rotatably mounted in the tubular member radially offset from the central longitudinal axis. The release mechanism includes a sleeve support surface that selectively engages the radially extending annular lip. The release mechanism is rotatable between a first position wherein the sleeve maintains a plug in a retained configuration and a second position, wherein the sleeve releases the plug into the tubular member.

Abstract: A fracturing device includes a power unit, and the power unit includes a muffling compartment, a turbine engine, an air intake unit and a cleaner. The air intake unit is communicated with the turbine engine through an intake pipe and configured to provide a combustion-supporting gas to the turbine engine; the cleaner is configured to clean the turbine engine; the air intake unit is at a top of the muffling compartment and the muffling compartment has an accommodation space, the turbine engine and the cleaner are within the accommodation space, and the cleaner is at a side of the turbine engine away from the air intake unit.

Abstract: Systems and methods for damping torsional oscillations of downhole systems are described. The systems include a damping system configured on the downhole system. The damping system includes a first element and a second element in frictional contact with the first element. The second element moves relative to the first element with a velocity that is a sum of a periodic velocity fluctuation having an amplitude and a mean velocity, wherein the mean velocity is lower than the amplitude of the periodic velocity fluctuation.

Abstract: An apparatus including a superstructure comprising: a vacuum collection pod comprising a vessel with a first opening near the base, a second opening near the top of the vessel for a vacuum system, and a third opening near the top of the cylindrical vessel for a hose delivering solid and liquid materials; a rotary airlock valve coupled to the first opening; a vacuum system attached to the superstructure, wherein the inlet of the vacuum system is in fluid communication with the second opening near the top of the vessel using a vacuum line; and a solids separator below the rotary airlock valve, the solids separator comprising a drill cuttings dryer, an effluent tank configured to collect effluent from the solids separator, and a centrifugal pump configured to remove the effluent from the effluent tank. Methods of treating drill cuttings include the use of the apparatus.

Abstract: A method of subterranean drilling comprising monitoring at least one drilling criteria at the surface; communicating a marker signal to a bottom hole assembly of a drill string upon meeting a condition of the at least one drilling criteria; and repeating the marker signal at least two consecutive times the condition is met. In an embodiment, the marker signal can be repeated every time the condition is met. A system for subterranean drilling comprising a drill rig adapted to monitor at least one drilling criteria at the surface; a communication element adapted to communicate a marker signal to a bottom hole assembly of a drill string upon meeting a condition of the at least one drilling criteria, wherein the communication element is adapted to communicate the marker signal to the bottom hole assembly at least two consecutive times the condition is met.

Abstract: A wellbore control device comprising a housing (1) defining a throughbore (2) for receiving a tubular, a first gate (4) having a first hole (6) and a second gate (3) having a second hole (5), piston rods (12a,12b) operably connected to the first and second gates (4,5), the first and second gates (3,4) being supported by the housing (1) and movable transverse to the throughbore (2) between an open position and a closed position, wherein the open position the first and second holes (5,6) are aligned with the throughbore (2), and wherein the gates (3,4) in the closed position split an upper portion (2?) of the throughbore (2) completely from a lower portion (2?) of the throughbore (2).

Abstract: Systems and a method for braking an object are provided. An example method, includes determining the expected speed of the object, monitoring the expected speed of the object, and determining if the actual speed of the object is within a preset tolerance of the expected speed. If the speed is not within the preset tolerance of the expected speed, a magnetorheological brake is activated to slow the object.