Abstract: A method of completing a wellbore is disclosed that in one non-limiting embodiment includes: placing a lower completion assembly that includes a flow device to provide fluid communication between the lower completion assembly and a production zone associated with the lower completion assembly; placing an isolation assembly with a packer above the lower completion assembly for isolating an annulus between the lower completion assembly and the wellbore; placing a flow restriction device above the packer; setting the flow restriction device in the annulus to restrict flow of fluid through the annulus; and setting the packer after setting the flow restriction device.

Abstract: This invention relates to a manipulation tool and method for connection and operation of a controllable well device and adapter. The tool includes an elongated housing with first and second end portions, a gripping device in the first end portion provides releasable engagement with the well device controllable by means of the manipulation tool. The gripping device includes means for resisting rotational and axial movement between the housing and the well device. At least one manipulation device is axially displaceable between a first and second position along a longitudinal axis of the housing and rotatable around the longitudinal axis of the housing. A first driving device produces axial displacement of the at least one manipulation device, and a second driving device produces rotation of at least one manipulation device. The first and second driving devices are connected to a control unit for controlling energy to the driving devices.

Abstract: A technique facilitates deployment of a communication line in a borehole, e.g. a wellbore, to enable monitoring of parameters along the borehole. A communication line is coupled with an anchor and conveyed into the borehole from a surface location. The anchor is then released at a desired location along the borehole with the communication line. The communication line is deployed from the anchor so as to extend along the borehole until reaching a desired uphole location, e.g. a location proximate the surface.

Abstract: A system for performing an operation in a wellbore comprises a tool (4) configured for deployment within the wellbore on an insulated slickline (6), and a winch (26) for hauling in and/or paying out the slickline. The system further comprises a winch controller (34) which is configured to receive information transmitted electrically from the tool along the slickline and to control the winch according to the received information. The tool may comprise a downhole tractor. The tool may comprise an electrical generator tool or a tool for performing a mechanical operation within the wellbore.

Abstract: A downhole tool that includes a cutter and jacking system and methods of using such a tool to remove a portion of casing or tubing from a wellbore. The tool may include an upper slip and a lower slip configured to selectively engage casing of a wellbore. A cutter and an extendable section may be positioned between the upper and lower slips. The cutter may be used to cut casing into an upper portion and a lower portion and the extendable section may be used to increase a distance between the upper and lower slips that moves the upper portion of the casing and the lower portion of the casing away from each other. The extendable section may be hydraulically actuated to move the upper portion of the casing away from the lower portion of the casing. The cutter may be an abrasive jet configured to cut the casing.

Abstract: Disclosed is a method and apparatus for performing a well completion. The apparatus comprises a tool string slidably locatable within the well and a shifting tool slidably locatable within the sleeve at an end of a tool string the shifting tool having a central bore therethrough and keys operable to be extended from an outer surface of the shifting tool when the central bore is supplied with the fluid above a predetermined pressure, the keys being engagable upon the sleeve so as to permit the shifting tool to move the sleeve longitudinally within the tubular body. The apparatus further comprises a motor located at a distal end of the tool string having a mill operably rotated thereby and means for selectably actuating one of the shifting tool or motor. The method comprises locating the tool string into the well and providing a fluid flow rate through the tool string to the first fluid flow range to actuate the shifting tool.

Abstract: A rotating control device can include an engagement member that secures relative to an outer housing an annular seal and/or a bearing, the member displacing in response to a pneumatic pressure differential. A method can include applying a pneumatic pressure differential, thereby displacing an engagement member that secures an annular seal relative to an outer housing, with rotation of the seal relative to the housing being permitted when the member is displaced to a position in which removal of the seal from the housing is prevented. A rotating control device can include a piston and an engagement member which secures an annular seal relative to an outer housing, the piston having piston areas exposable to a pneumatic pressure differential, and with increased pressure applied to another piston area of the piston displacing the piston to a position in which the member does not secure the seal relative to the housing.

Abstract: The disclosure relates to a seal assembly for a ram of a blowout preventer for sealing a wellbore penetrating a subterranean formation. The wellbore has a tubular to pass fluid therefrom. The rams are positionable about the tubular. The seal assembly includes a compound seal carried by the ram. The compound seal includes a face seal having a sealing surface sealingly engageable about the tubular and a support seal positionable adjacent to the face seal a distance from the sealing surface. The sealing surface extends along a front face thereof engageable with at least one of the tubular and the face seal of another ram. The support seal is non-engageable with the tubular during sealing and is more deformable than the face seal whereby the compound seal is supported during sealing.

Abstract: A valve assembly for wellbore, downhole or intervention operations, such as for subsea wellbore operations includes a rotatable valve member having a passage formed therein. The valve assembly is reconfigurable between a first configuration in which the passage is aligned or alignable with a first conduit, and a second configuration in which the passage is misaligned or misalignable with the first conduit, so as to cut or sever and/or clamp apparatus present in the valve member passage prior to reconfiguration. The assembly is configured to apply a maximum cutting force at a particular phase or stage of the reconfiguration.

Abstract: A fluid injection system includes a choke valve having at least one inlet. The system also includes a water injection line extending between a water supply and the choke valve, and the water injection line is configured to flow water from the water supply into a first inlet of the at least one inlet of the choke valve. The system also includes a polymer injection line extending from a polymer supply toward the choke valve, and the polymer injection line is configured to flow a polymer in a substantially non-inverted state from the polymer supply toward the choke valve. The choke valve is configured to receive the water and the polymer and to facilitate inversion of the polymer as the water and the polymer flow through the choke valve.

Abstract: A method of plugging a well includes providing a tubing in a wellbore, wherein in a location for a well plug, the tubing is provided with an internal cable section placed inside of the tubing and/or an external cable section placed outside of the tubing, the external cable section including a fluid-tight cable suitable for forming a sealing part of the well plug, and forming a plug in the well in the location for the well plug without pulling the tubing from the wellbore.

Abstract: A deep water drilling riser pressure relief system includes a drilling riser extending from a surface down to a BOP stack arranged subsea. The drilling riser comprises a drilling riser slip joint, an annular preventer arranged below the drilling riser slip joint, and at least one pressure relief device arranged in a lower part of the drilling riser. The at least one pressure relief device is configured to open so as to discharge a fluid from the drilling riser to the sea if a pressure difference between an inside and an outside of the drilling riser exceeds a pre-determined threshold.

Abstract: An apparatus can include a housing, a plunger configured to reciprocate along an axis within the housing, and an internal fluid chamber disposed in the housing. A valve, having a valve base and a deformable seal, can also be included in the apparatus. The apparatus can further include a seat having an aperture therein. The valve is configured to move into and out of contact with the seat when the plunger reciprocates within the housing, based upon a fluid pressure in the internal flow chamber. In addition, an outer diameter of the deformable seal of the valve is less than an outer diameter of the seat.

Abstract: A tubular actuation system includes a housing and an activatable sleeve including a first assembly having a first radially movable seat, a second assembly having a second radially movable seat, and an insert disposed between the first and second assemblies. The activatable sleeve is movable longitudinally from a first position to a second position, and from a second position to a third position within the housing.

Abstract: There is provided a method of stimulating a formation within a wellbore that is lined with a wellbore string, the wellbore string including a port and a flow control member, wherein the flow control member is displaceable relative to the port for effecting opening and closing of the port. The port is opened by displacing the flow control member in response to an applied pressure differential across a sealing interface. The port is closed by displacing the flow control member with hydraulic hold down buttons prior to removing the sealing interface and effecting pressure equalization.

Abstract: The laterally rotating height of a fill up and circulating tool that is mounted on one of the bails supporting an elevator is made shorter with integration of design components. A power cylinder features a hollow piston which integrates the mud line connected to the fill up tool. The hollow piston forms an integral part of the mud line. The mud line has an exterior slot with a longitudinal and a spiral component into which a pin extends that is supported by the cylinder. As the mud line descends the fill up tool moves initially axially followed by rotational movement to align with a sting for connection thereto. Raising the mud line reverses the movement pattern. The fill up tool is cantilevered from the mud line for its sole support. Height savings allows tool use with bails of varying lengths without interference.

Abstract: A modular top drive system for construction of a wellbore includes a motor unit. The motor unit includes: a drive body; a drive motor having a stator connected to the drive body; a trolley for connecting the drive body to a rail of a drilling rig; and a drive ring torsionally connected to a rotor of the drive motor and having a latch profile for selectively connecting one of: a drilling unit, a casing unit, and a cementing unit to the motor unit.

Abstract: Methods for designing lost circulation materials for use in drilling wellbores penetrating subterranean formations may involve inputting a plurality of first inputs into a numerical method, the plurality of first inputs comprising a lost circulation material property input of a first LCM; calculating a plurality of first outputs from the numerical method; inputting a plurality of second inputs into the numerical method, the plurality of second inputs comprising the lost circulation material property input of a second lost circulation material; calculating a plurality of second outputs from the numerical method; comparing the first outputs to the second outputs; and developing a drilling fluid comprising a third lost circulation material based on the comparison of outputs.

Abstract: A method for estimating an upscaled directional permeability of a formation includes: receiving a discrete fracture network (DFN), aligning the DFN in a desired direction; cropping the DFN to a desired size having boundaries. The method further includes identifying a fracture plane or fracture planes that are connected with each other and establish a path between the boundaries of the cropped DFN and creating a pipe model of the identified fracture plane or planes that includes one or more conduits connecting one boundary to another boundary. The method further includes creating a system of equations representing flows through the conduits, applying boundary conditions to the system of equations; solving the system of equations for steady-state flow to estimate the upscaled directional permeability of the formation. The method steps can be iterated for another desired direction if the upscaled directional permeability is wanted for the another desired direction.

Abstract: Described herein are gravel pack assemblies capable of performing complete gravel pack jobs when flow restricting devices, such as inflow control devices (“ICD”), are utilized. A gravel pack assembly includes a well screen attached to a flow restricting device and a relief valve. The relief valve is positioned in parallel with the flow restricting device so that the relief valve may provide an alternative path for fluid during dehydration of the gravel pack slurry, thus allowing extra fluid flow through the completion string during the gravel pack operation only.

Abstract: Method and apparatus are presented for perforating a subterranean formation so as to establish fluid communication between the formation and a wellbore by perforating a tubular with a mechanical perforator. The mechanical perforator comprises a perforator housing, a mandrel slidably positioned within the perforator housing, and at least one penetrator outwardly extendable from the perforator housing. When shifted axially the mandrel causes at least a portion of the at least one penetrator to extend outwardly from the perforator housing to perforate the tubular.

Abstract: A switch includes a casing having a bore, a piston assembly having a first end and an exposed end, a plurality of flanges formed at the first end; an insulating sleeve enclosing the first end, a contact assembly disposed in the casing bore; a pin disposed in the bore; a predetermined quantity of lubricant deposited in the bore; and a spring urging the pin into engagement with the piston assembly. The insulating sleeve and the plurality of flanges are at least partially disposed in the casing bore. The pin has: (i) a first position wherein the pin electrically contacts the piston assembly and is electrically isolated from the contact assembly; and (ii) a second position wherein the pin is electrically isolated from the piston assembly and electrically engages the contact assembly. The predetermined quantity of lubricant may be approximately 0.3 grams.

Abstract: An assembly for restricting fluid flow into a completion string of a well and restricting fluids based on one or more fluid characteristics is presented. The assembly includes an adjustable inflow control device. The adjustable inflow control device is for restricting flow of production fluids into the completion string. The assembly also includes a first autonomous inflow control device fluidly coupled to the inflow control device for restricting fluids based on one or more fluid characteristics. Others systems and methods are presented.

Abstract: A flow control system including a mandrel having one or more ports; one or more seals in sealing contact with the mandrel; a housing positioned about the mandrel and one or more seals and in sealing contact with the one or more seals. One or more diffusers placed in a fluid pathway of the flow control system. The one or more diffusers including an inner race having a bearing surface; an outer race having a bearing surface; an axially oriented wedge in contact with both the inner race and the outer race and configured to increase distance between the inner race bearing surface. The outer race bearing surface with wedge movement in one direction while permitting distance between the inner race bearing surface and the outer race bearing surface to decrease with wedge movement in an opposite direction.

Abstract: Embodiments of an improved bypass dart and assembly are described. In an embodiment, the plunger assembly includes a plunger having a first and second end. The plunger assembly may also include a cage attached to the second end of the plunger. Additionally, the plunger assembly may include a dart disposed within said cage. Further, the assembly may include an actuator coupled to the dart, the actuator configured to actuate the dart from a first position to a second position.

Abstract: Systems and methods for controlling an ESP installed in a well. The ESP is operated at a first voltage, and the current actually drawn by the ESP motor is monitored and compared to an expected current. If the actual current differs from the expected current, the actual horsepower load on the ESP motor is determined by multiplying an expected horsepower load by the ratio of the actual current to the expected current. A load saturation curve for the actual horsepower load is determined, and a voltage is identified on this curve at which the corresponding current is minimized. The ESP motor is then operated at this new voltage to optimize the efficiency of the motor.

Abstract: Various embodiments disclosed relate to delayed crosslinking compositions or reaction products thereof for treatment of a subterranean formation. In various embodiments, the present invention provides a method of treating a subterranean formation including placing in a subterranean formation a subterranean treatment composition including at least one of a delayed crosslinking composition and a reaction product thereof. The delayed crosslinking composition includes a crosslinker including a functionality chosen from —B(OH)2, —B?(OH)2, —O—B(OH)—O—B(OH)—O—, —O—B(OH)—O—B?(OH)(—O—)2, a salt thereof, an ester thereof, and a combination thereof. The delayed crosslinking composition also includes a glycol including at least one of a 1,2-diol and a 1,3-diol.

Abstract: A fluid injection system includes a water injection assembly having a choke valve configured to receive water from a water injection line and to provide the water to a main bore of a well head. The system also includes a polymer injection assembly having a dedicated polymer connection configured to receive a polymer from a polymer injection line and to direct the polymer toward the main bore of the well head to facilitate mixing of the water and the polymer within the main bore.

Abstract: A combustible foamed fluid energized with gaseous fuel and combustion oxidant sources. Also, an energized fluid system, a treatment method using the combustible foamed fluid, and a method to prepare the combustible foamed fluid are disclosed.

Abstract: A system recovers hydrocarbons from an unconventional reservoir using a number of sidetrack lateral wells. In addition, methods related to drilling the disclosed well system provide recovery of the hydrocarbons.

Abstract: Fluid data collected while drilling a wellbore in a drilling operation that includes a first well trajectory is received. A first productivity metric for a next section of the wellbore on a continued trajectory of the first well section trajectory is determined, based at least in part on the fluid data. A second well section trajectory for the next section of the wellbore different from the continued trajectory of the first well section trajectory is determined. A second productivity metric for the second well trajectory is determined.

Abstract: A method and computer-readable medium for selecting a wellbore for refracture is disclosed. A parameter is selected that is related a refracture decision and an influence value of the parameter on the refracture decision is determined. A first refracture score is estimated for a first wellbore based on a value of the parameter for the first wellbore and the influence value of the parameter. A second refracture score is estimated for a second wellbore based on a value of the parameter for the second wellbore and the influence value of the parameter. One of the first wellbore and the second wellbore is selected for refracture based on a comparison of the first refracture score and the second refracture score.

Abstract: A monitoring system includes a subsea laboratory configured to be positioned and operated below a sea surface. The subsea laboratory includes a housing, a fluid chamber within the housing and configured to receive a fluid from subsea drilling or production equipment, and a sensor within the housing and configured to generate a signal indicative of a characteristic of the fluid. The monitoring system also includes a controller having a processor configured to receive and to process the signal to determine the characteristic of the fluid, to determine an appropriate output based on the characteristic of the fluid, and to provide a control signal that causes an indication of the output via a user interface of a remote base station positioned above the sea surface.

Abstract: Disclosed are systems and methods of minimizing shock impacts assumed by electronics arranged within downhole tools. One disclosed tool string includes at least one downhole tool having an electronics package associated therewith, and an air shock tool having a housing operatively coupled to the at least one downhole tool and having a piston movably arranged within a piston chamber defined in the housing, wherein the electronics package is operatively engaged with the piston such that axial movement of the electronics package correspondingly moves the piston, and wherein a shock impact propagates through the tool string in an uphole direction and the piston is configured to reduce an effect of the shock impact on the electronics package.

Abstract: A wellbore assembly is provided that can include a first motor housing assembly member and a second motor housing assembly member that can bend relative to the first motor housing assembly at a bend location. The assembly can also include a magnet positioned to emit a magnetic field. A sensor can be magnetically coupled with the magnet and positioned to detect the strength of the magnetic field emitted by the magnet. Based on the strength of the magnetic field detected by the sensor, the amount of bend or bend direction of the second motor housing assembly member relative to the first motor housing assembly member can be determined.

Abstract: The present disclosure provides for a sensor assembly for use in a wellbore. The sensor assembly may include a rotating sub, the rotating sub coupled to a drill string and a drive shaft, the drive shaft coupled to the rotating sub. The sensor assembly may also include a nonrotating sub where the nonrotating sub is positioned generally around the drive shaft and shaft and rotatably coupled to the drive shaft and the rotating sub. The nonrotating sub may include an outer cover. The outer cover is generally tubular. The nonrotating sub may further include a sensor collar. The sensor collar is positioned within and coupled to the outer cover. The sensor collar may be coupled to the outer cover by a drive assembly. The drive assembly may include a motor adapted to rotate the sensor collar relative to the outer cover. The nonrotating sub also includes at least one positioning sensor coupled to the sensor collar.

Abstract: A method of transmitting data in a wellbore uses a signal receiver that is run into the wellbore on a working string. The signal receiver receives wireless signals from receiver communications nodes placed along the wellbore. The data from those signals is then sent up the wellbore, either by directing the signals directly up the working string, or by spooling the string to the surface and uploading the data. Sensors and associated communications nodes arc placed within the wellbore to collect data. The communications nodes may be the signal receiver nodes; alternatively, the communications nodes may send data from the sensors up the wellbore through acoustic signals to a receiver communications node. In the latter instance, intermediate communications nodes having electro-acoustic transducers are used as part of a novel telemetry system.

Abstract: A well having optically controlled switching, the well including a power cable run along a tubular string in a borehole, one or more downhole devices attached to the tubular string, one or more optically-controlled switches arranged downhole, where each switch is coupled between the power cable and one of the one or more downhole devices to enable or disable a flow of power to the downhole device, and a switch controller coupled to the one or more optically-controlled switches via an optical fiber, where each of the one or more optically-controlled switches are independently controllable.

Abstract: Systems and methods for detecting faults in the active damping of a logging tool are disclosed herein. A wellbore logging tool system comprises a processor, a memory, a wellbore logging tool comprising an acoustic transmitter, and a logging tool control module. The logging tool control module is operable to receive sensor signals from one or more sensors coupled to the wellbore logging tool after a damping control signal has been transmitted to the acoustic transmitter. The logging tool control module is also operable to determine one or more expected sensor signals, determine error values using the expected sensor signals and the sensor signals received from the one or more sensors, and compare the error values with one or more thresholds.

Abstract: A message to be sent from a downhole tool in a wellbore is modulated into a data uplink signal of pressure variations in the drill string. The pressure variations are generated by varying the torque on the rotor of the generator by varying the electric load on the generator. The pressure variation sequence of the data uplink signal may be selected from a look up table of known sequences. The message may be received by a surface receiver using one or more pressure sensors. The message may be demodulated from the detected pressure data using digital and analog signal processing. The frequency of the data uplink signal may be selected based in part on detected noise in the wellbore. The data uplink signal may be modulated using a spread spectrum protocol.

Abstract: A method includes obtaining measurements of a formation parameter prior to and after treatment of at least one formation penetrated a wellbore formed in the subsurface formation. The measurement correspond to a plurality of lateral depths of investigation. A difference is determined at each depth of investigation between the measurements made prior to and after the treatment. A skin effect is determined for each depth of investigation.

Abstract: Systems, methods and devices for analyzing a sample of fluid extracted from a hydrocarbon-producing geological formation to detect a quantitative amount of hydrogen sulfide or disclosed. The systems methods and devices involve including a scavenger within a sample compartment to react with the hydrogen sulfide therein. The concentration of hydrogen sulfide in the sample may be derived as a function of the amount of scavenger remaining in the sample after reaction with hydrogen sulfide, an amount of byproduct of a reaction between the scavenger and the hydrogen sulfide, or an amount of hydrogen sulfide as measured following a secondary reaction that releases the hydrogen sulfide from the scavenger.

Abstract: An oil well production analyzing system receives production fluid samples from the oil well according to an automated sampling schedule. The fluid samples are received within a degassing cylinder and separated into a liquid phase and a gas phase, with the liquid phase automatically transferred to a sampling cylinder for water cut analysis. Once the liquid phase has been transferred to the sampling cylinder, a piston within the degassing cylinder automatically evacuates all fluid from the cylinder in preparation of receiving a subsequent fluid sample from the oil well.

Abstract: A pick for mineral winning includes an elongate shank configured to be positioned into a cavity of a holder. A profile is defined on an outside surface of the shaft which includes a first surface formed into the profile and disposed to receive a leveraging device to enable a first forced translational movement of the shaft relative to the holder, and a second surface formed into the profile and disposed to receive the leveraging device to enable a second forced translational movement of the shaft relative to the holder.

Abstract: A cutting bit assembly includes a block, a bit sleeve, and a seal. The block includes a first bore and a fluid passage. The fluid passage includes a first portion and a second portion in fluid communication with the first portion. The first portion is oriented obliquely with respect to the first bore, and the second portion extends at least partially around the perimeter of the first bore. The bit sleeve includes a shank, a flange, and a second bore extending through the shank and the flange. The shank is positioned within the first bore of the block such that a surface of the flange engages a first end surface of the block. The seal is positioned between the second portion of the fluid passage and the shank to prevent contact between a fluid in the fluid passage and the outer surface of the shank.

Abstract: A mine mining system mining ore from a vein in a mine including a mining area provided inside an ore body, a first mine shaft provided inside the ore body, and a second mine shaft connecting the mining area and the first mine shaft to each other, the mine mining system includes: a transporting machine which loads the ore mined in the mining area and transports the ore to a soil discharge area while traveling in the first mine shaft; and a loading machine which stays in the second mine shaft, excavates the ore in the mining area, conveys the excavated ore in a direction moving away from the mining area, and loads the ore on the transporting machine.

Abstract: A rock drilling and bolting vehicle includes a drill feed adapted to slide on a drill feed rail and a bolter feed adapted to slide on a bolter feed rail. The vehicle includes a first wireless or ultrasonic transmitter disposed on the drill feed rail for transmitting a first signal, a second wireless or ultrasonic transmitter disposed on the drill feed for transmitting a second signal. The vehicle includes first, second and third wireless or ultrasonic receivers each capable of receiving the first signal and the second signal. A processor coupled to the receivers processes the signals to determine positions of the first and second wireless or ultrasonic transmitters.

Abstract: A steam turbine has a single-shell turbine casing and specific inner casings arranged inside the turbine casing. The steam turbine has a turbine casing with an outer wall, a turbine shaft mounted rotatably about a turbine axis in the turbine casing, a first turbine part, and at least one second turbine part which is arranged downstream of the first turbine part in the axial direction of the turbine shaft, wherein the expansion direction for steam conducted through the steam turbine runs from the first turbine part to the second turbine part, wherein between the first turbine part and the second turbine part, a sealing shell is arranged on the turbine casing, in particular on the inner side of the outer wall for rotation therewith, the sealing shell being formed in a sealing manner with respect to the turbine shaft via sealing elements.

Abstract: Embodiments of the invention relate generally to rotary machines and, more particularly, to the control of wheel space purge air in gas turbines. In one embodiment, the invention provides a turbine bucket comprising: a platform portion; an airfoil extending radially outward from the platform portion; a shank portion extending radially inward from the platform portion; an angel wing extending axially from a face of the shank portion; and a plurality of voids disposed along a length of the angel wing, each of the plurality of voids extending radially through the angel wing.

Abstract: Embodiments of the invention relate generally to rotary machines and, more particularly, to the control of wheel space purge air in gas turbines. In one embodiment, the invention provides a turbine bucket comprising: a platform portion; an airfoil extending radially outward from the platform portion; a shank portion extending radially inward from the platform portion; at least one angel wing extending axially from a face of the shank portion, the at least one angel wing including an angel wing rim extending radially upward toward the airfoil; and a plurality of voids disposed along the angel wing rim.