Abstract: A flow path assembly for a gas turbine engine is provided. The flow path assembly may include an outer casing comprising a metal material having a first coefficient of thermal expansion, a ceramic structure comprising a ceramic material having a second coefficient of thermal expansion, and a mounting component attached on a first end to the outer casing and attached on a second end to the ceramic structure. The mounting component may be constructed from at least two materials transitioning from the first end to the second end such that the coefficient of thermal expansion is different at the first end than the second end.

Abstract: An apparatus and method for perforating a subterranean formation is disclosed. The apparatus includes a tubular carrier; a charge tube disposed in the tubular carrier; and at least one shaped charge mounted in the charge tube which includes a casing, an explosive material and a liner enclosing the explosive material within the casing. An apex portion of the liner has a cross-sectional thickness greater than a cross-sectional thickness of any other portion of the liner. The cross-sectional thickness of the apex portion may be at least fifty percent thicker than a cross-section of a portion adjacent the apex portion. A density of the apex portion may be greater than the density of any other portions of the liner.

Abstract: An apparatus and method for perforating a subterranean formation is disclosed. The apparatus includes a tubular carrier; a charge tube disposed in the tubular carrier; and at least one shaped charge mounted in the charge tube which includes a casing, an explosive material and a liner enclosing the explosive material within the casing. An apex portion of the liner has a cross-sectional thickness greater than a cross-sectional thickness of any other portion of the liner. The cross-sectional thickness of the apex portion may be at least fifty percent thicker than a cross-section of a portion adjacent the apex portion. A density of the apex portion may be greater than the density of any other portions of the liner.

Abstract: An apparatus and method for perforating a subterranean formation is disclosed. The apparatus includes a tubular carrier; a charge tube disposed in the tubular carrier; and at least one shaped charge mounted in the charge tube which includes a casing, an explosive material and a liner enclosing the explosive material within the casing. An apex portion of the liner has a cross-sectional thickness greater than a cross-sectional thickness of any other portion of the liner. The cross-sectional thickness of the apex portion may be at least fifty percent thicker than a cross-section of a portion adjacent the apex portion. A density of the apex portion may be greater than the density of any other portions of the liner.

Abstract: An apparatus and method for perforating a subterranean formation is disclosed. The apparatus includes a tubular carrier; a charge tube disposed in the tubular carrier; and at least one shaped charge mounted in the charge tube which includes a casing, an explosive material and a liner enclosing the explosive material within the casing. An apex portion of the liner has a cross-sectional thickness greater than a cross-sectional thickness of any other portion of the liner. The cross-sectional thickness of the apex portion may be at least fifty percent thicker than a cross-section of a portion adjacent the apex portion. A density of the apex portion may be greater than the density of any other portions of the liner.

Abstract: The device contemplated provides a method for positioning the drill bit in a drilling operation to achieve small changes in hole angle or azimuth as drilling proceeds. Two different positions are available to the operator. The first is a straight ahead position where the tool essentially becomes a packed hole stabilizer assembly. The second position tilts the bit across a rotating fulcrum to give a calculated offset at the bit-formation interface. The direction that the bit offset is applied in relation to current hole direction is controlled by positioning the orienting pistons prior to each drilling cycle, through the use of current measurement-while-drilling (MWD) technology. Components of the tool comprise a MWD housing, upper steering and drive mandrel, non-rotating position housing, lower drive mandrel splined with the upper mandrel, rotating fulcrum stabilizer and drill bit.

Abstract: The device contemplated provides a method for positioning the drill bit in a drilling operation to achieve small changes in hole angle or azimuth as drilling proceeds. Two different positions are available to the operator. The first is a straight ahead position where the tool essentially becomes a packed hole stabilizer assembly. The second position tilts the bit across a rotating fulcrum to give a calculated offset at the bit-formation interface. The direction that the bit offset is applied in relation to current hole direction is controlled by positioning the orienting pistons prior to each drilling cycle, through the use of current measurement-while-drilling (MWD) technology. Components of the tool comprise a MWD housing, upper steering and drive mandrel, non-rotating position housing, lower drive mandrel splined with the upper mandrel, rotating fulcrum stabilizer and drill bit.

Abstract: The device provides a method for positioning the drill bit in a drilling operation to achieve small changes in hole angle or azimuth as drilling proceeds. Two different positions are available to the operator. The first is a straight ahead position where the tool essentially becomes a packed hole stabilizer assembly. The second position tilts the bit across a rotating fulcrum to give a calculated offset at the bit-formation interface. The direction that the bit offset is applied in relation to current hole direction is controlled by positioning the orienting pistons prior to each drilling cycle, through the use of current measurement-while-drilling (MWD) technology. Components of the tool comprise a MWD housing, upper steering and drive mandrel, non-rotating position housing, lower drive mandrel splined with the upper mandrel, rotating fulcrum stabilizer and drill bit.

Abstract: The device contemplated provides a method for positioning the drill bit in a drilling operation to achieve small changes in hole angle or azimuth as drilling proceeds. Two different positions are available to the operator. The first is a straight ahead position where the tool essentially becomes a packed hole stabilizer assembly. The second position tilts the bit across a rotating fulcrum to give a calculated offset at the bit-formation interface. The direction that the bit offset is applied in relation to current hole direction is controlled by positioning the orienting pistons prior to each drilling cycle, through the use of current measurement-while-drilling (MWD) technology. Components of the tool comprise a MWD housing, upper steering and drive mandrel, non-rotating position housing, lower drive mandrel splined with the upper mandrel, rotating fulcrum stabilizer and drill bit.

Abstract: A downhole drill system comprising a drill string, a drill bit terminating the drill string, a bent sub in the drill string above the drill bit, a motor housing in the drill string above the drill bit and a downhole sub connected within the drill string to the motor housing. The downhole sub comprises an adaptor housing in the drill string above the motor housing, a mandrel connected to the adaptor housing, the mandrel having a shoulder facing the adaptor housing, the mandrel shoulder and the adaptor housing together forming an annular recess, a kick pad mounted for rotation in the annular recess and movable around the annular recess when the mandrel is disengaged from the adaptor housing and a lock mechanism for locking the kick pad in a fixed position relative to the adaptor housing when the mandrel is engaged with the adaptor housing.

Abstract: A downhole sub for use in directional drilling with a bent sub attached to a drill bit. The drill bit is operated by a downhole motor. The downhole sub includes upper and lower tubular sections whose centers are offset from one another in the bend direction of the bent sub. The downhole sub includes an intermediate tubular section disposed between the upper and lower tubular sections, with the bore of the intermediate section included within overlap between extensions of each of the bores of the upper and lower tubular sections. The axes of the upper and lower tubular section are parallel and offset between about 1/4 inch and 2 inches. The intermediate section grades gradually into the upper and lower tubular sections. The downhole sub is used by incorporation into a drill string above the bent sub and spaced from the bend sufficiently to allow the drill string to use the downhole sub as a lever to force the drill bit into the wall of the borehole.