Abstract: A device and method for use is provided to provide a port in a tubular without using explosives or a mechanical apparatus. By the utilization of the chemical cutter described herein the decision on the type of completion equipment to be implemented may be delayed or modified as the well creation progresses.

Abstract: A safety valve includes a housing, a flapper coupled to the housing and movable between open and closed positions, and a flow tube movably disposed within the housing to retain the flapper in the open position. A lockout rod is coupled to the housing and movable between deployed and stored positions. The lockout rod is configured to retain the flow tube in an extended position when in the deployed position. A lockout ratchet element is arranged within the housing and coupled to the lockout rod. The lockout ratchet element is configured to retain the lockout rod in the deployed position.

Abstract: A system includes a valve subassembly configured to be disposed along an internal flowline exit of a first internal flowline within a downhole drilling module. The valve subassembly includes an active valve configured to regulate flow of a fluid through the internal flowline exit and a passive valve configured to be passively controlled based on a differential pressure between a first volume of the downhole drilling module and a second volume surrounding the downhole drilling module.

Abstract: An apparatus to limit movement of gripping members relative to an elevator includes a locking arm coupled to the gripping members and a first engagement arm. The locking arm includes a set of teeth disposed longitudinally thereon, and the first engagement arm includes a first set of complimentary teeth configured to engage with the set of teeth of the locking arm. The first engagement arm is moveable between a disengaged position, in which the first engagement arm and the locking arm are relatively moveable, and an engaged position, in which the first engagement arm allows the locking arm to move in a first direction but prevents the locking bar from moving in a second direction by more than a selected distance. The teeth of the locking arm engage the first set of complimentary teeth of the first engagement arm when the first engagement arm is in the engaged position.

Abstract: A method for heating a production fluid in a wellbore. The method can include heating, using a packer fluid, a working fluid flowing through a first medium disposed in a first section of the wellbore, where the first medium transfers heat from the packer fluid to the working fluid. The method can also include circulating the working fluid into a second section of the wellbore through a second medium, where the second medium transfers heat from the working fluid to the production fluid. The method can further include returning the working fluid to the first section of the wellbore through the first medium.

Abstract: A low-profile wellhead system having a nested hanger configuration, annular communication, elastomeric seals, and seal verification is provided.

Abstract: An indicator includes a body configured to be run within a tubular from a first portion to a second portion of the tubular, a sensor disposed at the body configured to detect when a tool run through the tubular has reached the body, and a signal generator configured to send notification that the tool has reached the body.

Abstract: A hydraulic setting tool. The tool is configured to allow hydraulic setting of a bridge plug, packer or other radially expansive mechanical well isolation mechanism. Wireline or slickline deployment may be utilized. In either case, parameters of the setting application may be recorded. In the case of wireline deployment such parameters and downhole data may be monitored in real-time allowing an operator to make intelligent setting application adjustments as necessary.

Abstract: Methods and apparatus for actuating a downhole tool in wellbore includes acquiring a CCL data set or log from the wellbore that correlates recorded magnetic signals with measured depth, and selects a location within the wellbore for actuation of a wellbore device. The CCL log is then downloaded into an autonomous tool. The tool is programmed to sense collars as a function of time, thereby providing a second CCL log. The autonomous tool also matches sensed collars with physical signature from the first CCL log and then self-actuates the wellbore device at the selected location based upon a correlation of the first and second CCL logs.

Abstract: A method for directional drilling of a wellbore includes automatically rotating a drill string having a steerable drilling motor at an end thereof in a first direction so that a measured torque related parameter thereon reaches a first value. The drill string is automatically rotated in a second direction so that the measured torque related parameter reaches a second value lower than the first value. A rate of release of the drill string is automatically controlled so that at least one of selected drilling fluid pressure and a range thereof is maintained.

Abstract: An apparatus for drilling a wellbore (10) is disclosed, the apparatus comprising a lowermost pilot drill bit (16) having a diameter less than that of the diameter of wellbore (12) drilled by the apparatus, above which is a reamer, having an adjustable drill diameter from a first diameter less than that of the pilot drill to a second diameter greater than that of the pilot drill, above which is a body portion (24) having a lower diameter less than that of the pilot drill and an upper diameter greater than that of the pilot' drill but less than the second diameter of the reamer.

Abstract: A packer is disclosed comprising a body with a first end and a second end, wherein the first end and the second end are configured to establish a connection with downhole equipment and wherein at least one of the first end and the second end is configured to establish a fluid flow between the downhole equipment, at least one guard drain, at least one sample drain, at least one guard drain flow line, at least one sample drain flow line configured to transport fluid flow from and to the at least one sample drain and one of the first end and the second end of the body, two swivel connections and a sealing element.

Abstract: Tubular drill string component for drilling a hole with circulation of a drilling fluid around the component and in a direction going from a drill hole bottom to the surface. The component includes a first end including a female threading, a second end including a male threading, and a substantially tubular central zone. The component includes a communication tube arranged at least in the central zone and in contact with a bore of the central zone. A signal transmission cable is arranged in the tube. The communication tube includes a body formed from at least one metal strip arranged with an annular component. The body includes, in section along a plane passing through the axis of the tube, at least two axially elongated lengths, partially overlapping one another with an axial play selected to accommodate the maximum elastic deformation of the component under axial compressive and/or bending stress.

Abstract: An apparatus and method to wipe a tubular member includes a first wiper section and a second wiper section, in which the first wiper section and the second wiper section are movable with respect to each other towards a point of convergence. The apparatus may further include a base having an aperture formed therein to receive the tubular member such that the first wiper section and the second wiper section are connected to the base and movable with respect to the base between an open position and a closed position.

Abstract: A mud motor bearing assembly for use in drilling a hydrocarbon well. The bearing assembly includes a bearing section containing stationary bearing rigs and rotating bearing rings in stacked arrangement. The bearing rings have wedge-shaped projections. The wedge-shaped projections of two adjacent stationary bearing rings form a recess to accommodate the projection of a rotating bearing ring in sliding engagement. The bearing assembly is capable of bearing both radial and axial loads.

Abstract: Methods and apparatus for conducting fracturing operations using a wellbore fracturing assembly are described. The assembly may be mechanically set and released from a wellbore using a coiled tubing string. The assembly may include a pair of spaced apart packers for straddling the area of interest, an injection port disposed between the packers for injecting fracturing fluid into the area of interest, and an anchor for securing the assembly in the wellbore. At least one of the packers includes a pressure balanced mandrel. After conducting the fracturing operation, the assembly may be relocated to another area of interest to conduct another fracturing operation.

Abstract: A diffuser assembly has pairs of split rings rotationally locked to each other in an alternating array with other pairs of split rings where adjacent pairs are responsive to pressure differential to be biased toward a sliding sleeve or the surrounding housing in an alternating pattern. The split rings are made to have an interference initial fit to the sleeve or housing and the splits on adjacent rings are offset while a relation of a projection to a depression between adjacent rings prevents relative rotation to keep the desired circumferential offset in the splits between adjacent rings. End tapers can bias adjacent pairs in opposed directions responsive to applied differential pressure. The rings are preferably metallic and can have a coating to facilitate relative sliding and enhance durability.

Abstract: A mobile rig for use in lowering a string comprising joints of a conduit into a well is provided with a rig transporter comprising a motorized unit, a mast assembly, a pivotal connection on the mast assembly with respect to the rig transporter. At least one hydraulic arm is pivotally mounted to the rig transporter and the mast assembly operable to move the mast to an upright position and for lowering the mast to a substantially horizontal position for transportation. In one embodiment, a top drive is mounted in the mast which is raised and lowered with the mast whereby the top drive is transported in the mast in the substantially horizontal position.

Abstract: A method for removing a tubular from a wellbore can include repeatedly and sequentially using an upper gripping member of an upper section and a lower gripping member of a lower section to hydraulically grip the tubular, while repeatedly and sequentially extending and retracting the upper section relative to the lower section to raise the tubular from the wellbore to a predetermined height. At least one lifting hole can be formed in the tubular, and a lifting member can be installed in each lifting hole. A hoist can be connected with each lifting member. The tubular can be cut using a saw and removed from the wellbore using the hoist.

Abstract: A method for providing one or more seals in an annular space between a well tubular and the surrounding formation or between pipes of a wellbore system includes determining an in-situ temperature, pressure, earth formation properties and one or more fluids present at one or more locations where the seals are desired. A sealing substance is placed at the locations and allowed to flow into the annular space and undergo curing to form one or more seals. The sealing substance may be a setting expoxy based, phenolic based or polyester based fluid that includes at least one solid component. The sealing substance has physical and fluid dynamic properties compatible with the determined in-situ parameters.