Abstract: A master ball valve with an integrated main hanger below the valve which may be used to hang jointed tubing, coil tubing, or electrified coil tubing for connection with an electric submersible pump.

Abstract: Embodiments of the present invention generally relate to an apparatus for supporting a tubular that more evenly distributes stress along the contact length of a tubular. In one embodiment, an apparatus for supporting a tubular is provided. The apparatus includes a bowl having a longitudinal opening extending therethrough and an inner surface for receiving a gripping member. The gripping member is movable along the surface of the bowl for engaging the tubular. The apparatus is configured so that an upper portion of the gripping member will engage the tubular before the rest of the gripping member engages the tubular.

Abstract: A technique is provided for processing well fluid downhole. The technique utilizes equipment for separating a well fluid downhole into a water component and an oil component. The separation of water and oil can be controlled by selecting an appropriately sized flow restrictor for use in limiting the flow of one or both of the water and the oil. Additionally, a sensor system is used to monitor a well characteristic that enables adjustment of the downhole fluid processing based on well characteristic data from the sensor system.

Abstract: A perforating apparatus (170) used to perforate a subterranean well. The perforating apparatus (170) includes a generally tubular gun carrier (106) and a charge holder (172) rotatably mounted within the gun carrier (106). At least one shaped charge (102) is mounted in the charge holder (172) and is operable to perforate the well upon detonation. A dynamically adjustable weight system (174) is operably associated to the charge holder (172). The dynamically adjustable weight system (174) includes a plurality of longitudinally extending tubes (176) that are operable to contain a weighted material therein and are operable to adjust the center of gravity (120) of the charge holder (172) such that gravity will cause the charge holder (172) to rotate within the gun carrier (106) to position the at least one shaped charge (102) in a desired circumferential direction relative to the well prior to perforating.

Abstract: Methods and devices with biasing force for sealing a well. Such a device is a blowout preventer has a body including a cavity having first and second recesses, a ram block configured to move inside the cavity, a top seat provided in the first recess and configured to seal the well when the ram block is closed, a wear plate provided in the second recess and configured to contact the ram block when the ram block moves inside the cavity over the wear plate, and a biasing element provided inside the cavity and configured to apply a biasing force on at least one of the top seat, the ram block or the wear plate to increase the sealing of the well.

Abstract: A swellable downhole packer (10) is provided for positioning downhole in a well to seal with the interior surface of a borehole or the interior surface of a downhole tubular. The packer includes a swellable elastomeric sleeve-shaped body (14) positioned over a mandrel (12) for swelling, and a rigid end ring (16,18). An elastomeric anti-extrusion member (20) is spaced axially between the sleeve-shaped body and the rigid end ring, and has a radial thickness adjacent the end ring greater than the radial thickness adjacent the sleeve-shaped body. A swellable elastomeric member (32) is spaced radially between the exterior surface of the mandrel and the elastomeric anti-extrusion member.

Abstract: A system isolates a control system for a downhole tool from the internal pressures in the tubing in which the tool is mounted. Opposed seals are used on a moving component in the tool so as to offset pressure induced forces regardless of the internal operating pressure of the tool. In a particular application to a subsurface safety valve the control system can be isolated from tubing pressure by offset seals between the passage and the flow tube or around exposed portions of the operating piston for the flow tube.

Abstract: An assembly for producing oil and/or gas through a well traversing stacked oil and/or gas bearing earth layers comprises a series of expandable packers and integrated perforating gun and sandscreen assemblies mounted on a production tubing such that each integrated perforating gun and sandscreen assembly is located adjacent an oil and/or gas bearing earth layer and at least one expandable packer is located between a pair of adjacent oil and/or gas bearing earth layers, and at least one inflow opening arranged in the wall of the production tubing adjacent to each sandscreen assembly. The integrated perforating gun and sandscreen assemblies are installed in a single run into the well such that uncontrolled fluid and/or sand influx into the well before installation of the sandscreens and expandable packers is avoided.

Abstract: A perforating apparatus (100) used to perforate a subterranean well. The perforating apparatus (100) includes a generally tubular gun carrier (106) and a charge holder (104) rotatably mounted within the gun carrier (106). At least one shaped charge (102) is mounted in the charge holder (104) and is operable to perforate the well upon detonation. A dynamically adjustable weight system (124) is operably associated to the charge holder (104). The dynamically adjustable weight system (124) is operable to adjust the center of gravity (120) of the charge holder (104) such that gravity will cause the charge holder (104) to rotate within the gun carrier (106) to position the at least one shaped charge (102) in a desired circumferential direction relative to the well prior to perforating.

Abstract: A downhole filter with a filter housing having a top filter and a bottom filter disposed therein. The filter housing can be in fluid communication with each filter. Each filter can be in fluid communication with a burst disk housing having a burst disk module and a burst disk. Each burst disk housing can be in fluid communication with the filter housing. Fluid can flow through the filter housing and through the filter. When a filter is clogged, the fluid can burst a burst disk, thereby bypassing the filter. The downhole filter can include a middle sub in fluid communication with the top filter and a second portion of the filter housing. The middle sub can threadably engage a bottom burst disk housing.

Abstract: A coiled tubing multi-zone frac system for fracing a formation adjacent a well using a sliding sleeve and erodible jets. Erodible jets can provide a means for perforating, fracing and flowing the well which takes the place of two separate tools that are otherwise needed to cause a well to flow, namely, this single tool replaces a perforating gun, a production sleeve.

Abstract: A drilling assembly in an elongated hole including a housing defining an interior with a plurality of motor stages in the interior. Each motor stage has at least one blade with supporting platform surfaces. A casing within the interior surrounds the plurality of motor stages and defines an annular flowpath with the housing. The casing also defines at least one offtake passage adjacent each motor stage. A shielding fluid passes through the annular flowpath and, in turn, the at least one offtake of each motor stage to coat and protect the at least one blade and supporting platform surfaces. A driving fluid passes through the casing for propelling the at least one blade of each motor stage. Preferably, the shielding fluid is at a relatively higher pressure than the driving fluid with a substantially constant ratio maintained between the between the shielding fluid and the driving fluid.

Abstract: A high capacity running tool sets and internally tests a casing hanger packoff during the same trip. The running tool has a stem and a body. The body is secured by threads to the stem of the running tool so that rotation of the stem relative to the body will cause the stem to move longitudinally. An engagement element connects the tool body to the casing hanger by engaging the inner surface of the casing hanger. Longitudinal movement of the stem relative to the body moves the engaging element between inner and outer positions and lines up ports in the stem and in the body for setting and testing functions.

Abstract: A wellbore servicing system, comprising a plurality of sleeve systems disposed in a wellbore, each sleeve system comprising a seat and a dart configured to selectively seal against the seat to the exclusion of other seats, the seats each comprising an upper seat landing surface and the darts each comprising a dart landing surface, wherein the darts each comprise a dart landing surface that is configured to complement an upper seat landing surface of the seat to which the dart is configured to selectively seal against.

Abstract: The invention relates to a drilling device and a related drilling method, in which provision is made for a mast, a drilling carriage that is guided along the mast in a displaceable manner and a drive unit for moving the drilling carriage on the mast. In accordance with the invention the drive unit has both a hydraulic cylinder drive and a rope winch drive. The drilling carriage can be coupled with the hydraulic cylinder drive and with the rope winch drive.

Abstract: A wellbore servicing apparatus, comprising a first mandrel movable longitudinally along a central axis and rotatable about the central axis, an orienting member configured to selectively interfere with movement of the first mandrel along the central axis, and a second mandrel connected to the first mandrel and configured to rotate about the central axis when the first mandrel rotates about the central axis. A method of orienting a wellbore servicing tool, comprising connecting an orienting tool to the wellbore servicing tool, identifying a predetermined direction, increasing a pressure within the orienting tool, rotating a portion of the orienting tool in response to the increase in pressure within the orienting tool, and rotating the wellbore servicing tool in response to the rotating of the portion of the orienting tool.

Abstract: A downhole swaging system includes, a tubular having an area of strength with a different resistance to swaging as compared to areas of the tubular outside of the area of strength, and a swaging tool. The swaging tool has a first swage, and a second swage with an adjustable swaging dimension, the second swage is in functional communication with the first swage such that the adjustable swaging dimension is adjusted in response to the first swage encountering a change in resistance to swaging.

Abstract: A manipulator apparatus carries tools for connecting drillpipes to the drillstring in a wellbore on a drilling platform. A telescopically extendable horizontal work arm is carried on a telescopically extendable vertical column, and the tools are to be mounted on a free end of the work arm. The column is manually rotatable about a vertical axis. The column and the work arm are each respectively formed of a fixed element and a telescopically extendable element. The fixed element is preferably formed of two U-profile members arranged back-to-back, and the extendable element includes an H-profile member with its web received between the webs of the two U-profile members. This forms a telescopic slide bearing of the H-profile member sliding along the two U-profile members. The hydraulic cylinders are received in the recessed spaces of the profile members.

Abstract: An expansion joint with one or more communication medium bypass paths is described herein. At least some illustrative embodiments include a first axially flexible cylinder, one or more additional axially flexible cylinders positioned within the first cylinder, and first and second annular members each positioned at a opposite ends of, and each coupled to, the first cylinder and the one or more additional cylinders (the first and second annular members each including one or more apertures through each member). All cylinders concurrently extend and contract in axial length when the first and second annular members are respectively moved away from and towards each other. Annular spaces formed by each of the one or more additional cylinders and an externally adjacent cylinder, together with corresponding apertures of each of the first and second annular members, each provides at least one path for at least one communication medium.