Abstract: A clamp for a downhole tool includes a sleeve having an axis and sleeve bodies. The sleeve bodies are coupled together on a first side of the clamp. Fasteners are used to mechanically lock the sleeve bodies together on a second side of the clamp to surround and clamp onto an exterior of a drill string having pipes. The pipes are coupled together at their coupled connections. In addition, recesses are formed in an exterior of each sleeve body. Inserts are mounted in the recesses to provide low friction exterior surfaces for the clamp.

Abstract: A stress-free centralizer system for wellbore tubulars having a centralizer portion with hollow vanes or solid vanes. An injectable material can be configured to harden at ambient or elevated temperatures and installed into the hollow vanes while coating a portion of the inner surface of the centralizer portion. Alternatively, a swellable encapsulation and shape shifting material can be used instead of the injectable material. Additionally, primers and adhesives can be used with the centralizer portion. Both materials when hardened or swollen can be configured to withstand temperatures and pressures within a wellbore for twenty-four hours without melting or degrading. The centralizer portion can simultaneously prevent axial movement and rotational movement while installed on the wellbore tubular, distribute load evenly around the centralizer portion, and provide cathodic protection to the wellbore tubular without using a stop collar with screws.

Abstract: An isolation liner incorporating a drill pipe and a swell packer, the swell packer configured to simultaneously cut and seals a wellbore, or slide down and seal a wellbore having a swellable section and a pair of end rings. The end rings couple the cylindrical body to the swellable wellbore packer section. Each end ring forms an annular abutment surface that cooperates with the swellable member to inhibit axial movement of the swellable member on the substantially cylindrical body. On each end ring, at least one diamond cutter insert, polyamide button, and/or tungsten carbide blocks is installed circumferentially and spaced apart symmetrically or near-symmetrically on the end ring.

Abstract: A drilling rig with mini-stabilizer tool for connecting to a measurement while drilling (MWD) system. The mini-stabilizer tool centralizes components in the wellbore for a more accurate measurement to protect measurement while drilling components from wear on shoulders of the measurement while drilling components. The mini-stabilizer tool accomplishes wear prevention by positioning the measurement while drilling components away from edges of the wellbore.

Abstract: A bidirectional stabilizer which reduces impact damage while rotating into and out of a wellbore. The bidirectional stabilizer can be coupled on a first end to a drill string and on a second end to a drill bit. The bidirectional stabilizer can have an annulus configured for maximum wellbore fluid flow. A cutting portion can be formed on a shaft with a plurality of helical blades between the first shaft end and the second shaft end. The plurality of helical blades of the cutting portion can be on a first plane and a plurality of cutting nodes can be on a second plane for smoothing a wellbore. The plurality of cutting nodes can have at least one impact arrestor mounted directly adjacent each cutting node.

Abstract: A bidirectional stabilizer, which reduces impact damage while rotating into and out of a wellbore. The bidirectional stabilizer can be coupled on a first end to a drill string and on a second end to a drill bit. The bidirectional stabilizer can have an annulus configured for maximum wellbore fluid flow. A cutting portion can be formed on a shaft with a plurality of blades between the first shaft end and the second shaft end. The plurality of blades of the cutting portion can be on a first plane and a plurality of cutting nodes can be on a second plane for smoothing a wellbore. The plurality of blades can have a wrap angle for forming a particle flow path between pairs of the plurality of blades configured with a line of sight parallel to the longitudinal axis.

Abstract: An end ring having a first ring with an inner diameter, a second ring with the inner diameter and a thickness 25 percent greater than the first ring; a shoulder with a sloped outer surface connecting the first ring to the second ring; a plurality of flutes formed in an outer surface of the end ring, a plurality of fastener holes formed in the first and second rings, wherein the end ring either slides over a first end of a base pipe and fastens together the base pipe and edges of a rubber tubular surrounding the base pipe; or slides over a first end of a frac tubular and fastens edges of a frac sleeve to the frac tubular. The invention includes a swell packer and a frac tubular having the end rings.

Abstract: A drilling rig with bidirectional dual eccentric reamer which forms a larger wellbore than originally drilled and larger than the drill bit diameter. The bidirectional dual eccentric reamer has a shaft with a longitudinal axis supporting a plurality of reamer portions. The reamer portions have a plurality of helical blades of varying thicknesses. The plurality of helical blades can have a plurality of cutting nodes and cutting inserts. The plurality of helical blades have a center of eccentric rotation which is offset from the longitudinal axis, thereby creating an eccentric rotation which allows for the formation of a larger wellbore than originally drilled and larger than the drill bit diameter.

Abstract: A bidirectional stabilizer and a drill string wherein the bidirectional stabilizer reduces motion while rotating into and out of a wellbore. The bidirectional stabilizer can be coupled on a first shaft end to the drill string and on a second shaft end to a bottom hole assembly or other downhole equipment. The bidirectional stabilizer can have an annulus configured for maximum wellbore fluid flow. A cutting portion can be formed on a shaft with a plurality of blades between the first shaft end and the second shaft end. The plurality of blades of the cutting portion can be on a first plane and a plurality of cutting nodes can be on a second plane for smoothing a wellbore.

Abstract: A swell packer configured to simultaneously cut and seal a wellbore or slide down and seal a wellbore. The swell packer has a swellable wellbore packer section and a pair of end rings. The end rings couple the substantially cylindrical body to the swellable wellbore packer section. Each end ring forms an annular abutment surface that cooperates with the swellable member to inhibit axial movement of the swellable member on the substantially cylindrical body. At least one diamond cutter insert, polyamide button, or tungsten carbide block can be installed circumferentially and spaced apart symmetrically or near-symmetrically on at least one of the end rings.

Abstract: A bidirectional dual eccentric reamer which can form a larger wellbore than originally drilled and a wellbore larger than the drill bit diameter. The bidirectional dual eccentric reamer can have a shaft with a longitudinal axis supporting a plurality of reamer portions. The reamer portions have a plurality of helical blades of varying thicknesses. The plurality of helical blades can have a plurality of cutting nodes and cutting inserts. The plurality of helical blades can have a center of eccentric rotation which is offset from the longitudinal axis, thereby creating an eccentric rotation. This allows for the formation of a larger wellbore than originally drilled and a wellbore larger than the drill bit diameter.

Abstract: A mini-stabilizer tool for connecting to a measurement while drilling (MWD) system. The mini-stabilizer tool centralizes components in the wellbore for a more accurate measurement to protect measurement while drilling components from wear on shoulders of the measurement while drilling components. The mini-stabilizer tool accomplishes wear prevention by positioning the measurement while drilling components away from edges of the wellbore.