Abstract: A rung lock frame has an upper rung portion, a lower rung portion integrally formed with the upper rung portion, and a bar member formed between the upper rung portion and the lower rung portion. The bar member defines an opening with the lower rung portion for the receipt of a rung of a ladder therein. The upper rung portion, the lower rung portion and the bar member are integrally formed of a glass-reinforced nylon material.

Abstract: A materials handling system (10) comprising a first (60) and second ladder (70) section connectable together to form a longer ladder, a tensioning system (100) attached to each section for tensioning the connected ladder sections, and a trolley (110) arranged to travel along the connected ladder sections, wherein the system includes a cable (158) and pulley for moving the trolley along the connected ladder sections.

Abstract: A bearing pressure system includes a bearing assembly having a first component movable against a second component and at least one accumulator in fluid communication with an interface between the first and second components, the at least one accumulator holding a pressurized fluid. A method includes providing a bearing pressure system having a fluid communicable between an accumulator and an interface between components movable relative to each other, providing an amount of pressurized fluid from the accumulator to the interface when the pressure of the fluid at the interface falls below a pressure range being maintained, and transferring an amount of the fluid from the interface to the accumulator when the pressure of the fluid at the interface rises above the pressure range being maintained.

Abstract: Creating pressure pulses for pulse telemetry for MWD tools using direct drive. Example embodiments include activating an electric motor of the MWD tool, and thereby turning a motor shaft. Rotating the motor shaft may cause turning of a threaded shaft. Turning the threaded shaft may cause a ball screw nut to translate along the threaded shaft. Translating the ball screw nut may cause translating a piston rod within a cylinder housing. Translating the piston rod may cause movement of the poppet coupled to the piston rod.

Abstract: The invention belongs to the technical field of drills for petroleum, coal mines and exploration, and provides a whipstocking drill for an ultra-short-radius well. The whipstocking drill comprises several flexible drill rods which are sequentially connected end to end, wherein the flexible drill rod at an end portion is connected with a length compensation device, and the flexible drill rods are externally sleeved with several guide sleeves which are movably connected. The invention solves the technical problems of a long whipstocking length and an excessively large turning radius of curvature during whipstocking.

Abstract: A down-the-hole drill hammer is provided that includes a housing, a drill bit proximate a distal end of the housing, and a roller bearing assembly. The roller bearing assembly circumscribes the drill bit. The roller bearing assembly includes a race and a plurality of rollers. The plurality of rollers are operatively engaged with the race.

Abstract: A frost removal system is for thawing frozen ground and a method removes frost from a selected area of frozen ground. The method can include providing at least one heat transfer device; auguring a hole into the frozen ground to at least a depth of the frost. The at least one heat transfer device is lowered into the selected area of frozen ground and self-augured to the predetermined depth. The at least one heat transfer device is heated and the heat is allowed to travel along a length of the at least one heat transfer device. Heat is applied from the at least one heat transfer device for thawing the selected area of frozen ground until the frost is removed. The removal system may also be used to remove moisture from saturated soil and to bake columns of soil with increased load-bearing capacity.

Abstract: A system including a rig site with at least one pollution control system located on the rig site. The pollution control system is configured to modify an output of light, noise, or vibrations from the rig site to an environment surrounding the rig site. Additionally, the pollution control system may include at least one active noise cancellation device, at least one active vibration cancellation device, and/or at least one active light control system to modify the light, noise, or vibrations.

Abstract: Techniques and systems to remove a portion of a drill floor from an offshore vessel. The drill floor may include an immovable section comprising a first portion of a surface area of the drill floor. The drill floor may also include a moveable section comprising a second portion of the surface area of the drill floor. Additionally, the drill floor may include an actuator configured to retract the moveable section from a first position to a second position to remove the second portion of the surface area of the drill floor.

Abstract: A vortex induced vibration suppression system including a buoyancy module dimensioned to at least partially encircle an underlying tubular, the buoyancy module having an exterior surface and a groove formed inwardly from the exterior surface; and a collar dimensioned to at least partially encircle the underlying tubular, the collar having a web, a set of flanges extending from the web, and at least one engaging member dimensioned to engage with the buoyancy module, when the collar is positioned around the underlying tubular.

Abstract: A downhole drilling assembly may comprise a sub secured between a drill string and a drill bit. The sub may comprise a cavity with a chassis housed therein. The drill bit may also comprise a cavity with an extender housed therein. This extender may provide access for various types of communication to reach into the drill bit's cavity. Several pairs of interfacing exchange surfaces may allow for communication (e.g. passing electrical, hydraulic, optical or electromagnetic signals) between these various elements. One pair of interfacing exchange surfaces, between the drill string and the chassis, may allow for communication regardless of relative rotational orientation. Two other pairs of interfacing exchange surfaces, one between the chassis and the extender and another between the extender and the drill bit, may require a specific rotational orientation for communication.

Abstract: A pump rod can include a body that includes a longitudinal axis; and a pin at an end of the body where the pin includes threads where the threads include tangential elliptical roots.

Abstract: Active stabilization is provided. In one possible implementation a drilling tool associated with a drill bit includes one or more rotation alteration devices configured to alter a rotational radius of a drill string. The drilling tool also includes at least one active stabilizer rotatively attached to the drilling tool, as well as a variable brake configured to control a rotation of the at least one active stabilizer relative to the drilling tool. In another possible implementation, a drilling tool includes an active stabilizer rotatably coupled to the drilling tool, as well as an actuation system configured to control a torque placed on the active stabilizer through contact with a wall of a borehole.

Abstract: A non-metallic centralizer for use with downhole operations. The centralizer is formed of a hollow, cylindrical body, a plurality of non-metallic blades protruding from the outer surface of the cylindrical body, and a plurality of wear buttons positioned on each of the plurality of blades, each of the wear buttons having a surface designed to reduce grabbing or sticking and wear of the hollow cylindrical body.

Abstract: A device includes a base configured to be coupled to a storage segment of a pipe support assembly. The device also includes an arm configured to be coupled to the base. The arm is configured to provide lateral support to a pipe when the pipe is disposed in a storage area adjacent to a first portion of the storage segment. The arm is also configured to move in a horizontal direction from a first location in which an end of the arm is disposed at a first horizontal distance from the storage segment to a second location in which the end of the arm is disposed at second horizontal distance from the storage segment when a force greater than or equal to a predetermined level is applied to the arm.

Abstract: A tool configured to facilitate installation or removal of a seal sub from an annular structure includes a support structure configured to be coupled to the annular structure, a shaft extending axially from the support structure, and an engaging structure coupled to the shaft. The engaging structure includes a plurality of engaging members, and each of the plurality of engaging members is configured to move in a radial direction between a retracted position that enables the engaging structure to be inserted into the seal sub and an extended position that enables the respective engaging member of the plurality of engaging members to engage the seal sub.

Abstract: A tubing hanger running tool includes an inner annular body, an outer annular body positioned circumferentially about the inner annular body, and an outer sleeve positioned circumferentially about the outer annular body and configured to move in an axial direction to actuate a hanger-to-wellhead lock ring to set the tubing hanger within the wellhead. The tubing hanger running tool also includes one or more control line adapters, wherein each of the one or more control line adapters are configured to fluidly couple a first passageway in the outer annular body to a second passageway in the inner annular body to provide a continuous control line path through the tubing hanger running tool as the tubing hanger running tool runs and sets the tubing hanger within the wellhead.

Abstract: A latching dog includes a dog body, at least one engagement arm protrudes from an outer radial surface of the dog body in a transverse direction, and at least one retention fin protrudes from the dog body in a longitudinal direction. The at least one retention fin maintains the latching dog engaged with a housing surface to keep the latching dog at a desired axial and/or rotational position while milling the housing and latching dog.

Abstract: A collecting device and method for loosening and collecting debris in a well, the collecting device includes a first end portion and a second end portion; a collecting receptacle between the first and second end portions, the collecting receptacle including at least one receptacle section and at least one screen receptacle section and at least one screen receptacle; a motor; and the collecting device, at its first end portion, including a feel pipe; a conveying screw in the feed pipe driven by the motor, the conveying screw being arranged to move the debris in towards the collecting receptacle and a tool at the leading end portion of the conveying screw.

Abstract: The method for stimulation of oil production involves the positioning of a downhole device at the operational depth of a well, the device being connected to a surface supply, and the excitation of elastic oscillations of certain distinct frequencies. Furthermore, bottom-hole clogging products are crushed and formation oil recovery is stimulated by a periodic impact on the bottom-hole zone of an ultrasound-range elastic oscillation field in a continuous mode and in a low-frequency pulse mode with simultaneous removal of clogging materials from the bottom-hole oil formation zone. In the continuous mode, the impact is carried out using a high-frequency oscillation of 16-25 kHz, and in the pulse mode, the impact is carried out at a frequency of 1-50 Hz. In terms of their design, the devices for stimulation of oil production consist of the following principal items of equipment: an ultrasound generator, a downhole ultrasonic emitter, a jet pump and a geophysical cable.

Abstract: A tool configured to dissolve in a selected subsurface environment includes a coating layer disposed about a particle core. The coating layer is formed from a plurality of substantially contiguous coated particles forming a substantially-continuous, cellular nanomatrix comprising a nanomatrix material.

Abstract: Provided are systems and methods for freeing differentially stuck pipe via the in-situ release of fluids from fluid-releasing tanks coupled to a centralizer or stabilizer of a pipe. Fluid-releasing tanks may be coupled to a centralizer or stabilizer of a pipe and located around the circumference of the pipe. Nozzles may be connected to the fluid-releasing tanks to enable the in-situ release of fluid from the fluid-releasing tanks. Various mechanisms may be used to open the nozzles and release the fluid from the fluid-releasing tanks.

Abstract: A downhole tool for connecting and selectively disconnecting within a wellbore first and second portions of a downhole tool string from each other. The downhole tool may include a first connector sub connectable with the first portion of the downhole tool string, a second connector sub connectable with the second portion of the downhole tool string, an internal chamber, and a fastener connecting the first and second connector subs. The fastener may fluidly separate the internal chamber into a first chamber portion and a second chamber portion. The first chamber portion may be fluidly connected with a space external to the downhole tool. The downhole tool may be selectively operable to disconnect the first and second connector subs from each other to disconnect the first and second portions of the downhole tool string from each other.

Abstract: A release mechanism for a jarring tool is formed by a plurality of segmented release lugs. Each lug includes a plurality of axial spaced projections on an inner surface and a plurality of grooves on an outer surface. The projections have either different widths or are separated by varying distances and releaseably engage corresponding grooves in a mandrel located within a housing of the tool. The release lugs are positioned between a trigger sleeve and the mandrel.

Abstract: The present disclosure relates to subsea tool apparatus and methods, particularly but not exclusively tool apparatus and methods relating to subsea trees or so-called “Christmas trees”. The subsea tool is for reinstating the functionality of a subsea tree valve actuator, by applying a thrust force to the subsea tree valve actuator stem, characterised in that: the tool gets its power supply to provide load on the actuator stem, directly or indirectly from the subsea tree SCM (subsea control module) supply.

Abstract: Various wellhead assemblies are provided. In one embodiment, the wellhead assemble includes a seal assembly that seals against an inner surface of a wellhead hanger and against an inner surface of a wellhead body. The wellhead hanger can be sized such that the upper portion of the hanger has an outer surface that abuts an inner surface of the wellhead.

Abstract: A system includes a hose fitting. The hose fitting includes a body, a fluid passage through the body, a first end portion, a second end portion, and a first floating seal insert. The first end portion and the second end portion are in fluid communication with the fluid passage. The first floating seal insert is disposed in the first end portion and is configured to damp one or more shockwaves having first characteristics.

Abstract: An adaptor is provided for a system including an electronic submersible pump. The adaptor includes a body including an upper surface and a lower surface opposite the lower surface. The body forms an adaptor passage and a channel. The adaptor passage extends along a vertical axis between the upper surface and the lower surface. The channel extends between the upper surface and the lower surface and is operable to receive a cable coupled with the electronic submersible pump. The channel extends in a direction that forms an angle relative to the vertical axis. The upper surface is operable to receive a valve assembly forming a valve passage that aligns with the adaptor passage.

Abstract: A wellbore liner-hanger tie-back system includes a bore receptacle coupled with a liner hanger at a downhole end of the bore receptacle, where the liner hanger is configured to be positioned in a wellbore, a tieback casing configured to be disposed in the wellbore, where a portion of an outer surface of the tieback casing is disposed proximate to an inner surface of the bore receptacle, and a seal system including at least one swellable seal. The seal system is disposed between the tieback casing and the bore receptacle to seal a space between the portion of the outer surface of the tieback casing and the inner surface of the bore receptacle.

Abstract: A well pump seal section housing connects between a pump and a motor. Upper and lower retainers at upper and lower ends of the housing have outward facing cylindrical walls. A bladder has an interior in fluid communication with dielectric lubricant in the motor. Rigid upper and lower sleeves are bonded within upper and lower openings of the bladder. The sleeves slide over the cylindrical walls of the retainers and are sealed by seal rings. Fasteners secure the sleeves to the cylindrical walls.

Abstract: Degradable downhole tools, tool components, and balls are formed from a polyvinyl alcohol (PVA) compound. The PVA compound exhibits strength and elasticity properties that are comparable to existing degradable downhole polymers and further exhibits degradability properties that are superior to existing degradable downhole polymers. For different components, the PVA compound may include a reinforcing material such as fiberglass. Usage of tools, tool components, and balls formed from the disclosed materials eliminates the requirement that such equipment be drilled out after use as the PVA compound quickly degrades in standard downhole fluids.

Abstract: A pressure control valve located in an improved tubing hanger of an oil or gas wellhead. The pressure valve having in-line communication with the production bore and having pressure activation. The pressure activation is imparted by utilizing hydraulic pressure input through the existing test port into the tubing head adapter void space. The pressure actuates the in-line wellhead control valve in a safer, more efficient, and less expensive manner than current industry practices and provides a barrier to pressurized hydrocarbons, both liquid and gas, produced by the well. The control valve eliminates the need for a lubricator and expensive specialized equipment. The valve is easily operated by a standard hydraulic hand pump through the existing test port of the tubing head adapter, and fits inside the tubing hanger.

Abstract: An example system includes a casing for insertion into a wellbore that includes one or more inflow control devices (ICDs). The ICDs may be disposed along the casing string to control the inflow of water into the wellbore. The system may include one or more controllers, each of which may be associated with an ICD. The controllers may be configured to receive a radio frequency identification (RFID) and to determine whether the associated ICD is a target for the RFID. A target ICD may be an ICD associated with a water cut zone. If the ICD is the target for the RFID, the controller is configured to control the ICD to open or close, thereby controlling the inflow of water. If the ICD is not the target for the RFID, the controller is configured to repeat the RFID.

Abstract: The invention relates to a fluid control device (500) for treating a well, to expand a liner (100) radially outward, said device comprising a piston (550) translatably mounted in said chamber (320), and degradable immobilization means (590), secured in translation with the piston (550), wherein the degradable immobilization means (590) are movable in translation in a cavity (700), wherein the device comprises protection means (800) isolating the cavity (700) from a discharge pipe (810) configured to introduce fluid degrading the pin (590) in said cavity (700), such that, in the initial state, the protection means (800) protect said degradable immobilization means (590), the protection means (800) being configured to break when the pressure in the cavity reaches a threshold pressure gap (?Ps) allowing degradation of the degradable immobilization means (900).

Abstract: A control valve assembly includes a body having a mud flow passage provided with a mud flow inlet and a mud flow outlet, a magnetic sleeve slidingly mounted to the body, and a solenoid mounted to the body adjacent the magnetic sleeve. The solenoid being selectively activated to shift the magnetic sleeve between a first position covering the mud flow outlet and a second position exposing the mud flow outlet allowing a pulse of mud to flow through the mud flow passage.

Abstract: A flow diversion valve comprising: a valve body including an upper housing releasably connected to a lower housing, the upper housing and lower housing being configured to receive a rotating rod therethrough; a shuttle positioned within the valve body, the shuttle being configured to move to cover one or more spill ports of the valve body; and a releasable locking member, wherein the releasable locking member is releasably connected to the valve body and positioned between the upper housing and the lower housing to assist in preventing relative movement therebetween.

Abstract: Methods, apparatus and systems for in-situ heating fluids with electromagnetic radiation are provided. An example tool includes a housing operable to receive a fluid flowed through a flow line and a heater positioned within the housing. The heater includes a number of tubular members configured to receive portions of the fluid and an electromagnetic heating assembly positioned around the tubular members and configured to generate electromagnetic radiation transmitted to heat the tubular members. The heated tubular members can heat the portions of the fluid to break emulsion in the fluid. Upstream the heater, the tool can include a homogenizer operable to mix the fluid to obtain a homogenous fluid and a stabilizer operable to stabilize the fluid to obtain a linear flow. Downstream the heater, the tool can include a separator operable to separate lighter components from heavier components in the fluid after the emulsion breakage.

Abstract: Various systems, methods, and devices are disclosed for handling contaminants in a wellbore or riser. A washpipe debris trap (WPDT) traps contaminants traveling up a wellbore from a downhole location, and the WPDT may serve as an indicator for a breached screen in a downhole location. A marine riser reversing tool (MRRT) may reverse the flow of fluid between a workstring conduit and an annulus between the workstring and the wellbore such that fluid rises to the wellhead with greater velocity. A bi-directional chamber trap (BDCT) may be utilized in a wellbore operation to remove contaminants from a fluid.

Abstract: A system for controlling a downhole component within a borehole, the system including a transfer assembly coupled between a rotatable component and the downhole component, the transfer assembly including a swash plate assembly configured to control the downhole component and a member configured to engage the swash plate assembly. The member is configured to move radially based upon a rotational speed of the rotatable component to selectively engage the swash plate assembly.

Abstract: A well telemetry system supplies power to downhole sensor nodes employed for obtaining telemetry data in oil wells. The nodes are held in the cement that lines the well and surround the casing. At the surface, an AC power unit is connected to the casing and geological structure that surrounds the cement. Power to nodes is supplied using an AC resonant circuit that generates standing waves of electrical power on the casing. Power from the standing waves is delivered to the nodes which are located at antinodes of the standing wave. The nodes are held in cement that surround the casing, with one of their two electrodes connected to the casing and the other connected to the cement or to geological structure.

Abstract: The invention is a method for operating a hydrocarbon deposit by injection of gas in foam form, comprising determining a model of displacement of the foam which is a function of an optimal mobility reduction factor of the gas and at least one interpolation function dependent on a parameter and constants to be calibrated. The mobility reduction factor of the gas is determined and the constants of at least one interpolation function are calibrated from experimental measurements comprising injections of gas in non-foaming form and in foam form into a sample of the deposit for different values of the parameter relative to the function being considered. Measurements of headloss corresponding to each value of the parameter of the interpolation function are considered. The calibration of the constants is performed interpolation function by interpolation function.

Abstract: A device for retrieving a control pod from a subsea BOP stack or deploying a control pod to a subsea BOP stack includes a base having a longitudinal axis, a first end, and a second end axially opposite the first end. The base includes a plurality of axially adjacent bays positioned side-by-side between the first end and the second end. Each bay is sized to hold one control pod. In addition, the device includes a trolley moveably coupled to the base. The trolley includes a first stall and a second stall axially adjacent the first stall. Each stall is configured to hold one control pod. Further, the device includes a housing fixably coupled to the base. Still further, the device includes a control pod actuation assembly coupled to the housing. The control pod actuation assembly is configured to move the trolley axially relative to the base and the housing to align each stall of the trolley with at least one bay of the base.

Abstract: A frac and gravel packing system including a tubular having a longitudinal axis, a wall defining an interior flowbore, a radial frac port and a radial production port extending through the wall in a first zone of an annular region surrounding the tubular; a screen surrounding the production port, the frac port not covered by the screen; a sleeve system including a sleeve longitudinally shiftable with respect to the longitudinal axis of the tubular, the sleeve configured to cover the frac port in a first position of the sleeve and uncover the frac port in a second position of the sleeve; and, a return path arranged to permit return fluid from a fracturing operation to exit the first zone of the annular region, wherein the return fluid passes through the screen prior to accessing the return path.

Abstract: A charge tube assembly for a perforating gun includes a charge tube configured to receive an explosive shaped charge, and a first endplate configured to couple to a first end of the charge tube, the first endplate including a first faceplate coupled to a first body, wherein the first faceplate includes a first material and the first body includes a second material that is different from the first material.

Abstract: A method of forming an initiator head assembly for an initiator is described. An initiator head assembly having particular application with a perforating gun assembly is also described. The initiator head assembly includes a body and an electrical contact component with the electrical contact component embedded therein. The initiator head assembly, with the embedded electrical contact component, is configured as a unitary component and holds a pressure differential across the top and bottom parts of the initiator head assembly.

Abstract: A system and method for confirming ignition of a fuel source in a wellbore. The system includes a tool, a fuel source associated with the tool, a control unit to ignite the fuel source, and a sensor to receive an ignition parameter corresponding to the fuel source. The ignition parameter indicates that ignition of the fuel source has occurred.

Abstract: A bypass plunger includes a unibody, or one-piece hollow body and valve cage, retains a dart valve within the valve cage portion using a threaded retaining nut secured by crimple detents, and includes sealable flow parts. A series of helical grooves surround the central portion of the outer surface of the hollow body of the plunger to control spin during descent. A canted-coil-spring disposed within the retaining nut functions as a clutch. The valve cage includes ports that may be configured to control flow through the plunger during descent. Other embodiments include clutch assemblies using canted-coil springs with split bobbins, and surfaced valve stems surfaced.

Abstract: An electrical submersible well pump assembly includes an electrical motor for driving a pump. A pressure compensating chamber contains a dielectric lubricant in fluid communication with an interior of the motor. A movable pressure compensating element has a first side in contact with the lubricant in the chamber. Movement of the element relative to the chamber causes a change in volume of the chamber. An electrical drive mechanism is connected with and moves the element. A controller senses a pressure difference between the lubricant pressure and the well fluid pressure and operates the drive mechanism in response. The element may be a piston, a bellows or telescoping tubes.

Abstract: A wellbore injection system comprises a tubing hanger mountable within a wellbore tubular, an injection conduit supported by the tubing hanger to extend into the wellbore tubular, and an injection valve mountable within the wellbore tubular and arranged in fluid communication with the injection conduit. The injection valve is removable from the wellbore tubular independently of the tubing hanger and injection conduit.

Abstract: A method relates to improving production rate and recovery of heavy oil or bitumen and reducing heat loss to over and under burden in a steam-assisted production process. The method includes strategically injecting recycled carbon dioxide into the reservoir between production wells. The heat insulation and solvent effects provided by carbon dioxide dissolved in the oil phase facilitate the desired improvement on oil recovery, and simultaneously sequester the CO2 back into the reservoir.