Abstract: A seal assembly for sealing an annulus between inner and outer wellhead members includes an energizer ring formed of a high strength elastic material having inner and outer legs. An annular inner recess with grooves on its base is formed on an inward facing surface of the inner leg. An inner diameter seal ring formed of an inelastic material engages the grooves of the inner recess. An annular outer recess with grooves on its base is formed on an outward facing surface of the outer leg. An outer diameter seal ring formed of an inelastic material engages the grooves of the outer recess. When the energizer ring is coaxially inserted in the annulus, the inner diameter seal ring is compressively and permanently deformed into sealing contact with the inner wellhead member, and the outer diameter seal ring is compressively and permanently deformed into sealing contact with the outer wellhead member.

Abstract: Method for repairing a hanger (D) of a liner (B), for making a leak-tight connection, the liner (B) being placed inside and in the continuation of the casing (A) of a well, the method consisting in axially positioning a metal tubular blank (1) in the well, the blank having a solid wall radially deformable beyond its elastic limit and comprising an upper cylindrical portion (10) whose outer diameter is slightly smaller than the inner diameter of the casing (A), a lower portion (13) also cylindrical whose outer diameter is slightly smaller than the inner diameter of the liner (B), and an intermediate portion (11, 12) of diameter varying between these two diameters, and causing radial expansion of at least one of these two cylindrical portions (10, 13) beyond its elastic limit so that they are applied closely and firmly and in leak-tight manner against the inner face of the wall opposite the casing (A) or liner (B).

Abstract: A multi-barrier seal system, including, a first seal assembly configured to provide a first sealing barrier between an auxiliary line and a mineral extraction system, and a second seal assembly configured to provide a second sealing barrier between the auxiliary line and the mineral extraction system, wherein the second seal assembly is configured to shear through the auxiliary line.

Abstract: An apparatus for use downhole is disclosed that in one embodiment may include a rotor having an outer lobed surface disposed in a stator having an inner lobed surface, wherein the inner lobed-surface or the outer-lobed surface includes a sealing material on a first section thereof and a metallic surface on a second section thereof.

Abstract: A downhole fluid flow control system (100). The downhole fluid flow control system (100) includes a flow control component (122) having an internal flow path (134) and a temporary sealing substance (136) disposed within the internal flow path (134). During installation of the downhole fluid flow control system (100) in a well, the temporary sealing substance (136) prevents fluid flow through the flow control component (122), which prevents plugging or clogging of the internal flow path (134). After installation, the temporary sealing substance (136) degrades when exposed to a water source in the well, which enables fluid flow through the flow control component (122) and thus proper operation of the fluid flow control system (100).

Abstract: Polycrystalline diamond compacts for cutting tools and rock drilling tools, and more particularly to very fine polycrystalline diamond compacts with a grain growth inhibitor layer and reduced abnormal grain growth. A method of fabricating such polycrystalline diamond material includes placing a powder layer of nano-sized grain growth inhibitor particles next to a mixture of diamond particles having an average particle size of about 1 micron or less and sintering at high pressure and high temperature to create a polycrystalline structure of sintered diamond grains. The sintered diamond grains have an average size of about 1 micron or less.

Abstract: The present disclosure relates to cutting elements incorporating polycrystalline diamond bodies used for subterranean drilling applications, and more particularly, to polycrystalline diamond bodies having high diamond frame strength and methods for forming and evaluating such polycrystalline diamond bodies. A polycrystalline diamond body is provided, having a top surface, a cutting edge meeting the top surface, and a first region including at least a portion of the cutting edge. The first portion exhibits a diamond frame strength of about 1200 MPa or greater, or about 1300 MPa or greater.

Abstract: An expansion system including a mandrel slidably coupled to plurality of primary cone segments that are interleaved with a plurality of secondary cone segments. The expansion system has a the first position wherein the primary cone segments and secondary cone segments are in a retracted position, a second position wherein the primary cone segments are in an expanded position and the secondary cone segments are in a retracted position, and a third position wherein the primary cone segments and the secondary cone segments are in an expanded position. When the expansion assembly is disposed within a tubular member and in the second position, the primary cone segments expand the tubular member into a tri-lobe cross-sectional shape.

Abstract: An apparatus for use in launching cement plugs in a well cementing operation, comprising: a cylinder (130); a piston (110) slideably received in the bore of the cylinder; and an actuator, operable by the piston, for launching a plug from the apparatus into the well; wherein the cylinder has a resiliently mounted latching member (132) positioned in the wall thereof and biased to project into the bore of the cylinder; and the piston has a profiled outer surface defining a recess (114) into which the latching member (132) can project to hold the piston in position in the cylinder.

Abstract: A wellbore rotating instrument system includes a source of rotational energy for transmission thereof to within a wellbore. At least one magnetic gear assembly is coupled at its input to an output of the source. A rotating load is coupled at its input to a rotational output of the magnetic gear assembly. The at least one magnetic gear assembly comprises a housing, a stator disposed in the housing proximate an inner wall thereof, a second shaft rotatably supported on bearings disposed at longitudinally spaced apart locations inside the housing and a first shaft rotatably supported inside the output shaft. The stator comprises a plurality of magnets disposed in generally circular laminations. The second shaft comprises a non-magnetic, electrically non-conductive body and a plurality of pole pieces disposed circumferentially therearound. The first shaft comprises magnets disposed around its exterior circumference and shaped to fit rotatably within the second shaft.

Abstract: Downhole tools for use in wellbores in subterranean formations comprise a body comprising at least one anomalous strengthening material. Methods of forming downhole tools for use in wellbores in subterranean formations comprise forming a body comprising at least one anomalous strengthening material. Methods of using downhole tools in wellbores in subterranean formations comprise disposing a body comprising at least one anomalous strengthening material in a wellbore in a subterranean formation. The at least one anomalous strengthening material may be exposed to a temperature within the wellbore higher than a temperature at a surface of the subterranean formation and a yield strength of the at least one anomalous strengthening material may increase.

Abstract: The head (80) comprises an upper portion for attaching and connecting to a cable (32) and a lower attaching portion for electrically connecting to a control and transmission module (82) of a tool to be lowered in the well. The head (80) comprises a hollow outer enclosure (94) and a mechanical connection assembly. The mechanical connection assembly comprises an attaching member (114) and a liner (116) defining an inner lumen (121) to receive the attaching member (114) and the lower end of the cable (32) The connecting head (80) defines a first downhole electrical path (70) able to extend from a lower segment (126) of the cable to a first connector of the control and transmission module (82), the first downhole electrical path (70) being completely electrically insulated from the outer enclosure (94).

Abstract: A method for stimulating a multi-zone wellbore completed with a string of production casing, including pumping a first volume of acidic fluid into the wellbore under pressure, and then injecting the first volume of acidic fluid into a first zone of interest along the production casing dropping at least one plug into the wellbore, the plug being fabricated from a material that substantially dissolves in the presence of the acidic fluid at or over a selected period of time.

Abstract: A well head cover includes a polymeric body integrally including a tubular shaped main body portion. A tubular shaped mounting portion extends from the main body portion. A tubular shaped discharge portion is connected to the main body portion and is oppositely directed with respect to the mounting portion. A first discharge tube bore is created through a first end wall provided in the discharge portion. A second end wall is provided in the mounting portion. The second end wall has an end wall portion through which a second discharge tube bore is created. An axial centerline of the second discharge tube bore is coaxially aligned with an axial centerline of the first discharge tube bore. A pipe extending through the well head cover has a diameter adapted to provide a sliding fit with the first and second end walls at the first and second discharge tube bores.

Abstract: A technique includes running a lower completion assembly into a well in a single trip. The lower completion assembly includes a screen, a first valve and a second valve. The technique includes performing a gravel packing operation using the lower completion assembly, where performing the gravel packing operation includes running a service assembly into the lower completion assembly to operate the first valve. The technique further includes removing the service assembly from the well and subsequently installing an upper completion assembly in the well. The installation of the upper completion assembly enables remote control of the second valve of the lower completion assembly for purposes of regulating the production of fluid from the well.

Abstract: A pressure relief valve assembly may be coupled to one or more casings and/or tubular members to control fluid communication therebetween. The valve assembly is a one-way valve assembly that relieves pressure within an annulus formed between adjacent casings and/or tubular members to prevent burst or collapse of the casings and/or tubular members. The valve assembly includes a tubular body having a port for fluid communication and a valve ring disposed within the tubular body, the valve ring having a flap for closing the port, wherein the flap is configured to flex from a closed position to an open position in response to a pressure differential. In another embodiment, the valve assembly also includes a retainer sleeve movable from an engaged position for maintaining the flap in a closed position to a disengaged position to allow the flap to open.

Abstract: A through tubing bridge plug (200) for providing a gripping and sealing engagement with a casing string of a wellbore. The bridge plug (200) includes an actuation rod (208), an anchor assembly (212), a pair of compression assemblies, each including a support assembly (216, 242) and an anti extrusion assembly (220, 238) and a packing assembly (224) disposed about the actuation rod (208) between the compression assemblies. Responsive to longitudinal movement of the actuation rod (208), the anchor assembly (212) establishes the gripping engagement with the casing string, the compression assemblies are radially deployed such that the anti extrusion assemblies (220, 238) are supported by the support assemblies (216, 242) and the packing assembly (224) establishes the sealing engagement with the casing string.

Abstract: A system for fracturing a formation includes a tubular positionable within a formation borehole having at least one port therethrough configured to provide fluidic communication from inside the tubular to the formation borehole. The system also includes a seal sealably attachable to both the tubular and walls of the formation borehole, a seat in operable communication with the tubular and a member in operable communication with the seat such that movement of the seat relative to the tubular causes the member to engage the walls and provide stress thereto.

Abstract: Magnetic composite particles can be used as proppants and allow for deliberate heating by applying an alternating magnetic field.

Abstract: A system for securing a first tubular to a second tubular including a housing having at least one group of at least one window therein. A gripping assembly is disposed in the housing and has at least one member operatively arranged for selectably extending through the at least one window for internally gripping the first tubular. A coupling unit is included having a first clamping mechanism and a second clamping mechanism. The first clamping mechanism is operatively arranged for externally clamping the housing, and the second clamping mechanism is operatively arranged for externally clamping the second tubular component. A method of securing together two tubular components is also included.