Workover Solutions, Inc.

Rival Downhole Tools Lc

Ashmin Holding LLC

Russell Wayne Koenig

Gunther H H Von Gynz-Rekowski

Kevin James Rudy

Michael V Williams

Mark Allen Reeves

William Christian Herben

Mark Joshua Miller

Steven Samuel Mitchell

Chaitanya P Challa

Frank R Vignal

Curtis E Leitko, Jr

Gunther Hh Von Gynz-Rekowski

Brandon Kaderka

Curtis E Leitko

A downhole separation system for use upstream of any tool through which a media flows. The separation system filters at least a portion of any solids from the media flowing through a filter flow path. The separation system flushes at least a portion of the filtered solids through a flush flow path, through a flush outlet on an outer surface of a housing, and into a space surrounding the housing. A screen and an activation mechanism are disposed within a housing inner bore. The filter flow path extends through a plurality of openings in the screen. The activation mechanism is configured to move between a default position in which it directs fluid through the filter flow path and an activated position in which it directs fluid through the flush flow path. Optionally, a spring within the housing inner bore is configured to bias the activation mechanism toward the default position.

Downhole separation system and method

A drilling assembly includes a particle adjusting mechanism upstream of a positive displacement motor. The motor includes a metal stator, a metal rotor at least partially disposed within the metal stator, and a motor gap defined between the sealing line of the metal rotor and the lobes of the metal stator. The particle adjusting mechanism adjusts a solid particle condition of a media flowing therethrough into a treated condition in which any remaining solid particles will travel through the motor gap without widening the motor gap to a failure gap size that causes the metal rotor to lock up or to rotate inefficiently slow. The particle adjusting mechanism adjusts the solid particle condition by removing, reducing a size, reducing a dimension, deforming, modifying a shape, dissolving, or chemically reacting at least a portion of any solid particles contained in the media. The drilling assembly is suited for high temperature wellbores.

Particle adjusting drilling assembly and method

A rupture disc configured to fluidly seal a passageway. The rupture disc includes a base extending from a distal surface to a proximal end, and a central portion extending across the proximal end of the base. The central portion traverses a central axis defined by the base. At least one surface of the central portion, such as an outer surface or inner surface, includes a plurality of facets defined by a plurality of seams. The facets may include one or more flat surfaces and/or one or more conical surfaces. A rupture disc system for fluidly sealing a portion of a wellbore includes the rupture disc disposed within and extending across a housing central bore of a housing, with one or more sealing members engaging the rupture disc and an inner surface of the housing central bore to fluidly seal the housing central bore.

Rupture disc and system

A drilling system for use in drilling a wellbore including a driving mechanism and a separation device disposed upstream of the driving mechanism. The separation device filters at least a portion of any solids from drilling media flowing through a filter flow path of the separation device. The separation device flushes at least a portion of the filtered solids through a flush flow path, through a flush outlet on an outer surface of the separation device, and into an annulus between the outer surface of the separation device and the wellbore. Optionally, the drilling system includes a second driving mechanism and a second separation device disposed above the second driving mechanism.

Drilling system with annular flush separation device and method

A bit saver assembly having an inner valve sleeve that actuates upon the weight-on-bit (WOB) of the drill bit exceeding a threshold value to overcome the countervailing force provided by a spring contained within the bit saver assembly and the internal flow pressure of the drilling fluid at the area of the inner valve sleeve. Actuation of the inner valve sleeve opens a fluid passage to the wellbore annulus resulting in a reduction of drilling fluid flow pressure and the stretch of the drill string thereby reducing WOB of the drill bit without operator assistance.

Bit saver assembly and method

A flow rate control system includes a housing and a valve assembly slidingly disposed within a housing inner bore. The housing includes bypass openings. The valve assembly includes a valve and an orifice disposed in a valve inner bore. The valve includes a plurality of valve bypass bores extending axially through a valve collar. The valve assembly slides between closed and fully open positions. A spring biases the valve assembly toward the closed position in which the valve closes the housing bypass openings. In the open position, a bypass fluid path is formed including the valve bypass bores and the housing bypass openings. The valve assembly is flow rate controlled in the closed position and pressure controlled in the open position. The valve assembly may slide within a sleeve assembly including sleeve bypass openings, which connect the valve bypass bores and housing bypass openings in the bypass fluid path.

Flow rate control system and method

A mechanically locking hydraulic jar device includes an outer sleeve, an inner sleeve partially disposed in an inner bore of the outer sleeve, and a mechanical lock engaging the outer sleeve and the inner sleeve in a default position to axially secure the inner sleeve to the outer sleeve. Activation of the hydraulic jar disables the mechanical lock to allow axial movement of the inner sleeve relative to the outer sleeve, which generates an impact force when the inner sleeve reaches an activated position. The hydraulic jar device also includes an upward block and a downward block configured to limit the upward and downward axial movement, respectively, of the inner sleeve relative to the outer sleeve when the mechanical lock is disabled.

Mechanically locking hydraulic jar and method

A vibration assembly includes a valve above a rotor and stator. The rotor rotates within the stator as fluid flows therethrough. The valve includes a rotating valve segment, which rotates with the rotor, and a non-rotating valve segment each including at least one fluid passage. In an open position, the fluid passages of the valve segments are aligned and a fluid flows through the valve. In a restricted position, the fluid passages of the valve segments are partially or completely unaligned, thereby creating a pressure pulse that is transmitted through the drill string or coiled tubing above the valve. The valve may further include an inner sleeve and an outer sleeve surrounding the non-rotating valve segment. The inner and outer sleeves allow axial sliding but prevent rotation of the non-rotating valve segment. The assembly may further include a lower thrust bearing at a lower end of the rotor.

Wear resistant vibration assembly and method

An apparatus including a rotating segment having a first radial surface, a non-rotating segment having a second radial surface, a housing disposed around the first and second radial surfaces, and one or more rolling elements disposed between and in contact with the first and second radial surfaces for transferring the non-rotating segment in an axial direction upon rotation of the rotating segment. The non-rotating element may be a second rotating element that rotates at a different rotational rate than the rotating element. Each rolling element moves 360 degrees along a circular path relative to the first radial surface and the second radial surface. The first or second radial surface has a tapered section. A downhole apparatus includes a power mandrel having a first end connected to a power section member and a second end having a rotating cam surface; a rotating element engaging the rotating cam surface; an anvil sub attached to a workstring, with the anvil sub having a stationary cam surface configured to engage with the rotating cam surface. Rotation of the rotating cam surface moves the anvil sub and the workstring axially within the wellbore.

Up drill apparatus and method

A downhole vibration assembly includes a valve positioned above a rotor that is disposed at least partially within a stator. The rotor is operatively suspended within an inner bore of a housing and configured to rotate within the stator as a fluid flows through the vibration assembly. The valve includes a rotating valve segment and a stationary valve segment each including at least one fluid passage. The rotating valve segment rotates with a rotation of the rotor. In an open position, the fluid passages of the valve segments are aligned and a fluid flows through the valve. In a restricted position, the fluid passages of the valve segments are partially or completely unaligned, thereby temporarily restricting the fluid flow through the valve to create a pressure pulse. The unobstructed pressure pulse is transmitted through the drill string or coiled tubing above the valve.

Vibration assembly and method

A downhole tool includes a valve assembly and a shock absorbing assembly. The valve assembly includes a valve spring operatively connected to a valve body. The shock absorbing assembly includes a spring operatively connected to a shock absorbing body having a fluid passage therethrough. The valve body is configured to selectively engage the shock absorbing body to create a fluid tight seal over the fluid passage in a first position, and to allow a fluid flow through the fluid passage in a second position. The repeated movement cycle of the selective engagement between the valve body and the shock absorbing body generates a pressure pulse or a varying pressure differential across the downhole tool. The repeated movement cycle is powered by a fluid flow. The tool may be selectively activated and deactivated.

Downhole extended reach tool and method

A downhole apparatus connected to a workstring within a wellbore. The workstring is connected to a bit member. The apparatus includes a mandrel operatively connected to a downhole motor mechanism, an anvil member operatively formed on the bit member, the anvil member being operatively connected to the mandrel, a radial bearing housing unit operatively connected to the workstring, with the radial bearing housing unit being disposed about the mandrel, and a hammer member slidably attached to the radial bearing housing unit.

Growing community of inventors

Conroe, TX, United States of America

Russell Wayne Koenig