Abstract: In a coiled tubing assembly for use in a wellbore, the tubing assembly uses longitudinally spaced apart clamping members to clamp two or more coiled tubing members alongside one another. Each clamping member includes a clamping portion extending circumferentially about each coiled tubing member so as to be rotatable in relation thereto, and a connecting portion joined between the clamping portions. A longitudinal positioning element is fixed relative to one of the tubing members in association with each clamping member such that the clamping member remains pivotal relative to the positioning element and the tubing members upon which it is fixed. The longitudinal positioning element thus only restricts the respective clamping assembly in the longitudinal direction along the tubing members without restricting relative twisting between the tubing members.

Abstract: An offshore drilling vessel includes a floating hull subjected to heave motion. The hull includes a moonpool and a drilling tower near the moonpool. A drilling tubulars storage rack is provided for storage of drilling tubulars. The vessel includes a heave motion compensation support that is adapted to support a slip device while performing heave compensation motion relative to the heaving motion of the vessel. A racking device is provided with a heave motion synchronization system that is adapted to bring a tubular retrieved from the storage rack in heave motion into a vertical motion that is synchronous with the heave compensation motion of the string slip device. The racking device includes vertical rails and at least two separate motion arm assemblies mounted on said vertical rails. Each separate motion arm assembly includes its own vertical drive which is electrically connected to the heave motion synchronization system.

Abstract: An extension member for coupling a tapered stress joint to a basket coupled to a porch extending from an offshore platform is disclosed. In an embodiment, the extension member includes a central axis, a first end, and a second end opposite the first end. In addition, the extension member includes a radially inner surface extending axially from the first end to the second end. The inner surface includes a first mating profile proximate the first end that is configured to engage a radially outer surface of the tapered stress joint. Further, the extension member includes a radially outer surface extending axially from the first end to the second end. The outer surface includes a second mating profile proximate the second end that is configured to slidingly engage a mating profile within the basket.

Abstract: A drilling drive system is provided. The drilling drive system has a mast having a longitudinal axis and a surface extending along the longitudinal axis. A bar is fixed to the surface of the mast and extends along the longitudinal axis. A plurality of rungs is disposed along the length of the bar, and a floating chain is disposed around the mast. A drive sprocket has a plurality of teeth that engage the plurality of rungs and the floating chain.

Abstract: The invention relates to a drive of a slide of an earth drilling device having a rotary drive and a pinion that is driven by the rotary drive and can be engaged with a rack, wherein the rotary drive is engaged with another pinion which can be engaged with the rack.

Abstract: A pipe gripping apparatus is disclosed having a plurality slips slidably mounted on corresponding slip support surfaces disposed radially the vertical axis of a central opening. The slip support surfaces include an upper region having a radially outwardly curved surface and a lower region having a flat inwardly tapered surface with respect to the vertical axis of the central opening. Powered actuators and a timing ring pivotally linked to the slips move the slips towards and away from each other along their corresponding slip support surfaces to engage and release a pipe. Move of the slips fully upward and outward along outwardly curved slip support surfaces will substantially remove the slips from the central opening to prevent obstruction of the central opening by the slips.

Abstract: A rotary slip bowl includes a tubular body having a central bore with an internal surface. The internal surface includes a tapered profile extending from a top surface to a generally straight profile. The rotary slip bowl also includes one or more umbilical grooves in the internal surface, wherein each umbilical groove is dimensioned to partially house an umbilical line. A rotary slip system includes the rotary slip bowl and a rotary slip set configured to be partially housed within the central bore. The rotary slip set includes two or more slip segments separated by spaces. One of the spaces is aligned with each umbilical groove of the rotary slip bowl. A handle is affixed to an upper end of a slip segment with the handle positioned adjacent to one of the spaces. The rotary slip system may further include a carrier for transporting the rotary slip bowl.

Abstract: A racking arm assembly is adapted to be mounted on a drill floor of a drilling rig and includes a lift arm assembly having a first arm that is movably coupled to a vertical support column, wherein the lift arm assembly is adapted to be raised and lowered along a vertical length of the vertical support column during a pipe handling operation. A lift jaw assembly is pivotably coupled to a second arm of the lift arm assembly and includes a lift jaw assembly having a lift jaw gripping apparatus that is adapted to grip and fixedly hold a drill pipe stand proximate a pin end of the drill pipe stand during the pipe handling operation. The lift jaw gripping apparatus is further adapted to be rotated relative to the lift arm assembly about a substantially horizontal axis while the lift jaw gripping apparatus is fixedly holding the drill pipe stand.

Abstract: An aqueous-based downhole fluid having a lubricant therein may be circulated within a subterranean reservoir wellbore where the downhole fluid may be or include a drilling fluid, a completion fluid, a fracturing fluid, a drill-in fluid, a workover fluid, and combinations thereof. The lubricant may include a clay stabilizer and a vegetable oil derivative, such as but not limited to, a sulfonated vegetable oil. The downhole fluid may include the lubricant in an effective amount for lubricating a first surface.

Abstract: Apparatus and method for limiting the expansion and contraction of a production tubular within a pumpjack oil well includes an anchor having a hydraulic dampening chamber and an expansion joint. A piston is attached to the tubular and position within the hydraulic dampening chamber so that axial expansion and contraction of the tubular caused by thermal and loading forces is resisted by the constrained movement of the piston within the hydraulic chamber.

Abstract: Certain aspects are directed to tools for setting production packers or actuating other downhole tools in response to activation signals received via an electrical control line within the wellbore. In one aspect, a downhole assembly for a wellbore is provided. The downhole assembly can include a reservoir and a pressuring module in fluid communication with the reservoir. The reservoir can contain a control fluid in communication with a fluid control path of a downhole tool. A quantity of the control fluid can be transmitted via the fluid control path for actuation of the downhole tool. The quantity of the control fluid can be controlled using a pressure change in the control fluid. The pressure change in the control fluid can be caused by the pressurizing module in response to an activation signal received by the pressurizing module via an electrical control line coupled to the pressurizing module.

Abstract: Provided herein are methods and apparatus for collecting and preserving core samples from a reservoir. In some embodiments, a method includes obtaining core samples from a reservoir using a rock and fluid sampling tool and depositing the core samples in a vessel filled with a hydrogen-free fluid such that a portion of the hydrogen-free fluid is displaced by the core samples and the core samples are immersed in the hydrogen-free fluid. The method also includes transferring a gas into the vessel to occupy a space in the vessel and sealing the vessel via a cap on an end of the vessel. Methods of analyzing the core samples core samples collected from a reservoir and a rock and fluid sampling tool are also provided.

Abstract: A method of removing a wellbore isolation device comprising: causing or allowing at least a portion of the isolation device to undergo a phase transformation in the wellbore; and milling at least a portion of the isolation device that does not undergo the phase transformation.

Abstract: A casing section comprising: a body comprising a wall; a window, wherein the window is an opening in the wall of the body; and a covering, wherein the covering: (A) is composed of a composite material; (B) is located on the outer surface of the body; (C) covers the window; and (D) spans at least a sufficient distance beyond the perimeter of the window such that the casing section has a desired pressure rating at the location of the window. A method of creating a lateral wellbore in a subterranean formation comprising: introducing a casing string into a wellbore, wherein the casing string comprises at least one casing section; drilling through at least a portion of the covering from the inside of the casing string to expose the window; and forming the lateral wellbore adjacent to the exposed window.

Abstract: A system, in certain embodiments, has a composite seal with both a metal shell and an elastic core, such as an elastomer core. In one embodiment, the composite seal has an annular metal shell with a top, a bottom, and a seal interface disposed between the top and the bottom. The composite seal also has an elastomer disposed within the annular metal shell, wherein the elastomer is configured to impart pressure against the seal interface.

Abstract: Systems and methods for performing operations on a well include first and second flow control devices positioned between upper and lower sections of a conduit. An upper connector assembly engaged with the upper section includes connectors adapted for connection to a chemical stimulation device, a blowout preventer, or other well intervention apparatuses. A lower connector assembly engaged with the lower section includes connectors adapted for connection to a chemical stimulation device, a running tool, wellbore conduits, or other well intervention apparatuses. The two connector assemblies, above and below the flow control devices, enable sequential or simultaneous operations to be performed, and can enable operations to be performed independent of the state of the flow control devices.

Abstract: An annular seal having a sealing member and method for use is provided for sealing an item of oilfield equipment. The annular seal has an inner diameter for receiving the item of oilfield equipment and a frame. The seal member is contiguous with the frame. The annular seal is configured for durability, in that it resists wear, inversion, increases lubricity, enables tightness, and/or otherwise generally increases endurance, toughness, and/or permanence.

Abstract: A restrictor device for controlling a return flow of drilling fluid from a borehole where drilling fluid is provided from a surface installation via a drill string to a bottom-hole assembly is disclosed. Drill pipes forming the drill string are provided with pipe joints including enlarged-diameter pipe portions. An annulus is formed between a riser and the drill string. The annulus is in fluid communication with a drilling-fluid flow path. The restrictor device is arranged in the annulus. The restrictor device includes a restrictor pipe anchored to the riser and surrounds at least one restrictor element placed on an intermediate pipe portion that connects two enlarged-diameter pipe portions. The length of the restrictor device exceeds the largest distance between two consecutive restrictor elements. The restrictor element is a drill-pipe/casing protector with an external diameter larger than a diameter of the pipe joints.

Abstract: An obturator for actuating a downhole tool having a central bore. The obturator comprising a body of a size and shape to pass through the central bore of the tool and an engagement member releasably attached to the exterior of the tool body, the engagement member being of a size and shape to engage and actuate the tool.

Abstract: An annular seal, in certain embodiments, includes a top seal section, a bottom seal section, and a core seal section including non-orthogonal top and bottom faces relative to a radial axis of the core seal section disposed between the top seal section and the bottom seal section. The core seal section is configured to expand radially when an axial load is applied to the top and bottom faces of the core seal section such that the top and bottom faces are deformed into an orthogonal alignment relative to the radial axis of the core seal section.

Abstract: An expandable anchor/seal is pushed up a ramp until making contact with the surrounding tubular as or after the anchor/seal contacts the same tubular. The setting sleeve is made from high yield steel that has a weakened leading end to reduce the force required to push the leading end and the anchor/seal and an outer surface treatment at a leading end that engages or penetrates the wall of the surrounding tubular. Preferably a plurality of fingers are formed with axially oriented slots starting from a leading end allowing fingers to flex as they ride up the ramp on the mandrel for setting the anchor/seal and locking that set with the setting sleeve exterior surface configuration that can abut or penetrate the surrounding tubular.

Abstract: An apparatus for supporting tubing in casing includes a setting tool and a liner top packer, which can be used for tieback. A setting slip is disposed uphole of a packing assembly on the packer and is movable from a retracted to an extended state engaging the casing. The setting tool has a temporary connection to the packer and has a pack-off that seals the tool in the packer but allows for movement. After running downhole, the temporary connection of the setting tool to the packer is disconnected, and the setting slip is set in the casing by moving the setting tool in an uphole direction. To set the packing assembly, the packer is moved in the uphole direction by engaging the setting tool with the pack-off and compressing the packing element (e.g., packing element and opposing cones and slips) against the set setting slip. Eventually, the setting tool is disconnected from the packer by disengaging the pack-off.

Abstract: A cement retainer comprises a plug that may be run into casing on a wire line and set in a conventional manner. A passage through the plug allows cement to be pumped therethrough. A wiper plug follows the cement, wipes the inside of the casing and latches onto the retainer to prevent back flow of cement. In some embodiments, the cement retainer and wiper plug are made of drillable materials allowing a series of squeeze operations to be conducted, one after another without undue delay, and then be drilled up in a single bit run. In some embodiments, the cement retainer and wiper plug are made of metals, drillable or non-drillable, or other long lived materials in order to plug wells in the process of abandoning them.

Abstract: A chemical reaction heat source for use in heaters used in down-hole applications is provided. The heat source has a fuel composition that comprises thermite and a damping agent. The use of the thermite mix enables the heaters of the present invention to generate hotter temperatures down wells. This in turn allows the use of Bismuth/Germanium alloys, which have higher melting points, to enable the production of plugs for the abandonment of deeper wells where subterranean temperatures are higher.

Abstract: Apparatus, in the form of a eutectic alloy plug (1) and a deployment heater (10) are provided. The plug (1) and the deployment heated (10) are provided with means (5, 13) for releasably retaining the deployment heater (10) within a cavity (4) in the plug (1). The nature of the retaining means is such that once the plug (1) is secured in a well the heater (10) can be recovered without the plug (1). An extraction heater (20), which is also receivable within the cavity (4) of the plug (1), is provided to re-melt the eutectic alloy and thus enable the extraction of the plug from a well. Various method of plugging abandoned wells are made possible by the control that the provided apparatus gives.

Abstract: In a method of sealing a fracture (1) in a formation (2) surrounding a wellbore provided with a non-cemented perforated liner (4), a placement tool (6) is introduced into the liner and so positioned that a sealing fluid outlet (7) of the placement tool is located at the fracture (1). A placement section (8) including the sealing fluid outlet is pressed against the liner. A placement fluid is caused to flow into the fracture and controlled to obtain a desired fluid flow in an annular space (5) between the liner and the formation that is directed in downstream direction at a position upstream the fracture and that is directed in upstream direction at a position downstream the fracture. When said desired flow is obtained, sealing fluid is ejected from the sealing fluid outlet. A sealing system is furthermore disclosed.

Abstract: A system for blending cement and at least one additive during a blending job to create a cement slurry for use in an underground hydrocarbon well includes a mixing tub, at least first and second blenders and a rotatable platform upon which the blenders are mounted. Each blender includes at least one elongated, rotatable, mixing blade extending into the tub to mix the cement and at the additive(s) to form the cement slurry.

Abstract: A method for reverse circulation cementing of a liner in a wellbore extending through a subterranean formation is presented. A running tool with expansion cone, annular isolation device, and reverse circulation assembly is run-in with a liner. The annular isolation device is set against the casing. A valve, such as a dropped-ball valve, opens reverse circulation ports for the cementing operation. The liner annulus is cemented using reverse circulation. An expandable liner hanger, if present, is expanded into engagement with the casing. The running tool is released and pulled from the hole.

Abstract: The present disclosure relates to a system for controlling an extraction of landfill gas flow (LFG) from a plurality of wellheads at a landfill. The system has a first wellhead located at the landfill, a first processor having a first rule set, and a first LFG flow control valve controllable by the first processor. A second wellhead is located at the landfill in a vicinity of the first wellhead and has a second processor and a second LFG flow control valve. The second processor has a second rule set and is operable to control the second LFG flow control valve. The first and second processors use their said rule sets to control the first and second LFG flow control valves, respectively, to control an LFG flow through their said first and second wellheads, respectively.

Abstract: A flow and fluid conditioning pressure reduction valve or device includes an inlet and an outlet. The valve or device includes at least one relatively long flow bore conduit shaped as a spiral or a spiral arranged on the surface of a disc or cone. Each spiral shaped conduit includes at least one rotation and each spiral shaped conduit may be closely packed. The conduit arranged between the inlet and the outlet has reduced flow cross section area, and the length, the cross section area, and the number of the spiral shaped conduits in line determine the pressure reduction of a given fluid at a given flow rate.

Abstract: A tubing string assembly for fluid treatment of a wellbore includes substantially pressure holding closures spaced along the tubing string, which each close at least one port through the tubing string wall. The closures are openable by a sleeve drivable through the tubing string inner bore.

Abstract: A downhole actuator (30) comprises a tubular housing (34) which includes an indexing profile (42) on an inner surface thereof, and an indexing sleeve (46) mounted within the housing (34). The indexing sleeve (46) comprises an engaging arrangement including first and second axially spaced engagement members (52, 54) which cooperate with the indexing profile (42) of the housing (34) to be sequentially engaged by an actuation object (48) passing through a central bore (50) of the indexing sleeve (46) to drive the indexing sleeve (46) one discrete step of movement through the housing (34) towards an actuation site.

Abstract: Systems and methods for reducing or removing condensate blockage in a natural gas wellbore and a near-wellbore formation. Microwaves are used to heat a ceramic-containing material within a near-wellbore formation. Heat is transferred from the ceramic-containing material to the near-wellbore formation. Any gas condensate reservoirs in the near well-bore formation are heated, and condensed liquids accumulated around the wellbore are re-evaporated.

Abstract: A downhole diffuser assembly comprising a diffuser adapted to reside within a carrier sub. The diffuser assembly includes an upper mounting member mountable within the carrier sub and having an fluid inlet port, and a lower section having a diffuser screen. A plurality of cutters are removably attached to the diffuser screen, wherein the cutters are radially oriented relative to a central axis of the diffuser screen. The cutters may extend internal or external to the diffuser screen, depending on the desired downhole conditions. In a preferred embodiment, a first set of cutters is mounted at a first selected height along the central axis of the diffuser screen, and wherein a second set of cutters is mounted at a second selected height along the central axis of the diffuser screen.

Abstract: A method and apparatus for removing debris from a wellbore using a cleaning tool. The tool may comprise an inner mandrel and a cup member coupled to the inner mandrel. The cup member is moveable between a collapsed position where fluid may flow across the exterior of the cup member, and an extended position where fluid is diverted into a flow path disposed between the inner mandrel and the cup member. The fluid is diverted through a filter member that is coupled to the inner mandrel below the cup member.

Abstract: A sand control screen assembly includes a base pipe defining one or more flow ports that provide fluid communication into an interior of the base pipe. A sand screen is arranged about an exterior of the base pipe and thereby defines a production annulus between the exterior of the base pipe and the sand screen. A prepack porous media is positioned in and fills the production annulus. A flow collector is positioned within at least one of the one or more flow ports and provides a retainer and a mass of porous media positioned within the retainer.

Abstract: An expandable device comprising a plurality of expandable cells. The cells may be bistable cells or other types of cells that are expanded from a contracted position towards an expanded position. Additionally, the cells may be combined with locking mechanisms to hold the structure in an expanded position.

Abstract: An apparatus and method for puncturing a pipe in-situ is presently disclosed. The apparatus has an actuator in communication with a remote controller. A firing assembly has a firing chamber and a firing pin, wherein the firing pin is in communication with the actuator. The firing chamber is configured to hold and fire a bullet radially toward the pipe, upon the firing pin being actuated with the actuator. The method includes the steps of inserting a pipe puncturing apparatus into a pipe, activating an actuator, communicating the activation of the actuator to a hammer and moving a firing pin in the hammer to impinge a cartridge and fire a bullet.

Abstract: A lipless tubular oil seal assembly uses a tubular type of seal. The new seals create only enough pressure against the casing to provide an adequate seal under most conditions and the small amount of oil that would leak by on the roughest well casing surfaces acts as a lubricant. The new seal has no lip so it cannot turn under and get stuck in the well casing like a cup seal, even under the roughest conditions.

Abstract: Herein are provided tools and processes for extracting oil from subterranean formation. The processes can include lightening the oil in the formation prior to extraction by the addition of a nanogas solution. The tools include injectors for the formation of the nanogas solution within the subterranean formation.

Abstract: There are provided high power laser perforation, hydraulic fracturing systems, tools and methods for the stimulation and recovery of energy sources, such as hydrocarbons, from a formation. These systems, tools and methods provide predetermined laser beam energy patterns, to provide for the down hole volumetric removal of custom geometries of materials, sealing of perforations, reperforations, refractures and other downhole actives.

Abstract: A completion assembly designed to perforate a section of casing along a wellbore, comprises a perforating gun, a canister, and a locator device. The canister contains ball sealers that are dimensioned to seal perforations, while the locator device is a casing collar locator that senses the location of the assembly within the wellbore based on the spacing of casing collars. The completion assembly also includes an on-board controller configured to send an actuation signal to the perforating gun to cause one or more detonators to fire when the locator has recognized a selected location of the completion assembly, thereby perforating the casing, and to release the ball sealers from the canister. Methods for seamlessly perforating and fracturing multiple zones along a wellbore are also provided, using a select-fire perforating gun.

Abstract: A one trip system for perforating and fracking multiple intervals uses a releasable barrier. The barrier can be an inflatable. A pressure booster system is associated with the BHA so that the existing hydrostatic pressure is boosted when the gun or portions thereof are fired. After firing in one interval, the BHA is raised and the barrier is redeployed and the pattern repeats. Instruments allow sensing the conditions in the interval for optimal placement of the gun therein and for monitoring flow, pressure and formation conditions during the fracturing. Circulation between gun firings cleans up the hole. If run in on wireline a water saving tool can be associated with the BHA to rapidly position it where desired. A multitude of perforation charges mounted in the BHA can be selectively fired by selected corresponding detonator based on a predetermined sequence or surface telemetry command.

Abstract: Three-phase separation is achieved downhole in a production well by forming an oil/liquid separation zone in the well between two packers which are positioned between producing and disposal zones. Gas is permitted to separate above the top packer. A pump is used to pump an oil/water mixture from above the top packer into the separation zone. Adequate residence time is permitted in the separation zone to achieve the separation. A check valve in the bottom packer is used to provide pressure to raise the oil to the wellhead. A control valve at the wellhead is used to control pressure in the separation zone and the relative sizes of the streams issuing therefrom.

Abstract: A method for detecting stick-slip in a drillstring includes (a) measuring a parameter that is a function of a torque applied to the drillstring by a top drive system over a selected time period, the measuring being performed by at least one surface sensor that produces measurement data including torque values over a frequency range; (b) filtering out measurement data that has a frequency outside a selected frequency band, the selected frequency band including a resonant frequency of the drillstring; (c) identifying a minimum and a maximum torque value in the filtered measurement data and determining a difference of these two values; (d) determining a surface stick-slip index by dividing the difference of the maximum and minimum torque values by an average torque value over the selected time period; and (e) displaying the surface stick-slip index on a display.

Abstract: A methodology and system promote hydrocarbon production from a reservoir using steam assisted gravity drainage. The technique comprises deploying sensors in a subsurface environment containing the reservoir. The sensors are used to obtain data on properties related to a steam assisted gravity drainage region of the reservoir. Based on the data collected from the sensors, the amount of steam injected into areas of the reservoir may be adjusted to facilitate, e.g., optimize, production of hydrocarbons.

Abstract: A brake device for engaging an inner surface of a drill string within a borehole. The brake device has a driving member that defines a plurality of wedge surfaces, a brake retainer that receives at least a portion of the driving member, and a plurality of braking elements positioned in contact with at least a portion of the outer surface of the driving member. The brake retainer has a biasing member that is operatively coupled to the driving member. The biasing member of the brake retainer biases the driving member in a proximal direction relative to the longitudinal axis of the drill string to position the wedge surfaces in contact with corresponding braking elements, and the wedge surfaces drive the braking elements radially outwardly to engage the inner surface of the drill string. The brake device is not coupled to an inner tube assembly.

Abstract: Methods of determining a pH of a wellbore fluid within a wellbore in communication with a subterranean formation comprise introducing carbon quantum dots into a wellbore fluid, exposing the wellbore fluid to radiation from an electromagnetic radiation source, and measuring at least one fluorescence property of the carbon quantum dots within the wellbore fluid to determine a pH of the wellbore fluid. Related methods of determining a pH of a fluid within a wellbore extending through a subterranean formation are also disclosed.

Abstract: A downhole wireless actuation based pipe lifting system with wireless communications and data acquisition capabilities for lifting casing from a well formation. The system may be deployed along a casing string with centralizers in the closed position to prevent any resistance that would be created by the centralizers. Upon reaching the proper location in the well, one or more pipe lifting systems may be actuated to lift the pipe from the well formation thereby providing a path for cement to flow around the casing. The system may collect, and store data before, during, and after the cementing process is performed, and may transmit the data wirelessly or by cable.

Abstract: A system for use in a wellbore can include a first transceiver that is operable to transmit a wireless signal. The first transceiver can be positioned in an electrically isolated chamber between a tubular and a casing string for confining a transmission of the wireless signal to within the electrically isolated chamber. The system can also include a second transceiver that is positionable in the electrically isolated chamber for receiving the wireless signal from the first transceiver.