A method for lifting a first well tubular nested in a second well tubular from contact with the second well tubular includes moving a wellbore intervention tool to a location where the first well tubular is in contact with the second well tubular. The well intervention tool is operated to displace a wall of the first tubular until either (i) the wall of the first tubular contacts the second tubular and separates the first tubular from contact with the second tubular, or (ii) an opening is made in the wall of the first tubular. After the opening is made, an object is displaced from the wall of the first tubular until the object contact the second tubular and lifts the first tubular from the second tubular, wherein a circumferentially continuous annular space is opened between the first well tubular and the second well tubular.

The present disclosure provides methods for bonding a first downhole tool to a borehole tubular, which include applying solder particles, each particle having an outer shell and a core of liquid metal, to at least one of a surface of the first downhole tool or a surface of the borehole tubular. The methods may also include rupturing the shells of the solder particles to release the liquid metal cores. The methods may further include bonding the first downhole tool to the borehole tubular by allowing the released liquid metal core to solidify.

A system may include an electromagnetic (EM) logging tool for inspecting downhole tubulars. The EM logging tool may include a mandrel, at least one low-frequency transmitter coil disposed on the mandrel, at least one-low frequency receiver coil disposed on the mandrel, and at least one-high frequency sensor configured to measure one or more electromagnetic properties of a tubular.

Provided is an inner string and a well system. The inner string, in one aspect, includes an inner tubular including a sidewall having a thickness (t.sub.3), the inner tubular having an orientation port extending entirely through the sidewall to provide fluid access from an interior of the inner tubular to an exterior of the inner tubular. The inner string, according to one aspect, further includes a weighted swivel located around the inner tubular, the weighted swivel including an orientation slot, the orientation slot configured to align with the orientation port to provide a pressure reading indicative of a relative location of the inner tubular to the weighted swivel.

A high efficiency smart steering drilling system includes a smart push force application tool and a centralizer. The centralizer is at an end close to a drill bit. The smart push force application tool is at an end away from the drill bit and includes a push force application wing rib having a telescoping function. The smart push force application tool is capable of automatically measuring an inclination angle and an azimuth angle and comparing the inclination angle and the azimuth angle with design values so as to control the push force application wing rib to output a push force in a telescopic manner based on a difference between the measured values and the design values and applying a push force to the drill bit. The drilling system achieves combined deflection under double action of drill bit push and pointing, greatly improving the deflection capability.

A stop collar for mounting to a downhole tubular includes: a cylindrical housing having a threaded inner surface and a tapered inner surface; a compressible slip ring having teeth formed in an inner surface thereof and a pair of tapered outer surfaces; a solid cam ring having a tapered inner surface; and a cylindrical bolt having a threaded outer surface. A natural outer diameter of each ring is greater than a minor diameter of the threaded surfaces. Screwing the threaded surfaces of the housing and the bolt is operable to drive the tapered surfaces together, thereby compressing the slip ring such that the teeth engage a periphery of the tubular.

High frequency oscillation (HFO) comes in at least two types. Type 1 HFO is lower frequency and often associated with a motor. Type 2 HFO is higher frequency and often independent of a motor. To mitigate torsional strain due to Type 2 HFO, an HFO mitigation mechanism can be placed based on an oscillation node location to move the oscillation node to a new position which may be uphole of a tool or the BHA, or to a less vulnerable location. Mitigation can also include placing an energy damping component based on the oscillation node. This may be at a high displacement location distanced from the oscillation node, or may include placement at the oscillation node with an additional HFO mitigation mechanism to move the oscillation node away from the installation location. Oscillations may be damped by using any combination of flow restrictions, fluid bypasses, or axially compliant elements.

A downhole tool has a tool body with an outer diameter equal to a borehole diameter, at least one cavity formed in and opening to an outer surface defining the outer diameter of the tool body, a light source, a filter, and a light detector mounted in the at least one cavity, and a window disposed at the opening of the at least one cavity, wherein the window encloses the cavity.

A non-electric explosive device includes a primary body containing cutting material and including a primary charge positioned in the cutting material; an explosive body at a first axial end of the primary body and including explosive material; and a firing head at a second axial end of the primary body, the firing head including a firing pin secured at least partially inside the firing head via securing device, the firing pin comprising an activating end proximate the primary charge and a blunt end protruding from a distal end of the firing head. A force applied to the blunt end of the firing pin causes the firing pin to retract toward the primary charge and break the securing device so that the activating end of the retracting firing pin impacts the primary charge which ignites the explosive material that causes the cutting material in the primary body to travel radially outward.

A technique facilitates formation of a gravel pack along relatively lengthy wellbores. According to an embodiment, a completion system comprises a plurality of screen assemblies. The completion system also has an alternate path system disposed along the plurality of screen assemblies. The alternate path system includes shunt tubes, e.g. transport tubes, coupled together by jumper tubes. An anti-buckling structure is coupled to each jumper tube to prevent buckling when high operational pressures, e.g. operating pressures of 9000 psi or higher, are applied to the alternate path system.