Teledrill, Inc.

Baker Hughes Corporation

Advantage Downhole Systems, LLC

Robert Paul MacDonald

Gabor Vecseri

Benjamin Jennings

Volker Krueger

Roger W Fincher

John W Harrell

Kyle Lamar Taylor

Hatem N Nasr

Ford Douglas Creighton

The tool assembly includes a main body and a bypass assembly. The main body has an off-set through bore and a cavity to fit the bypass assembly. The cavity includes a cavity surface, a first fluid bypass port, a second fluid bypass port, and a pressure inlet port. There is also a flow restrictor in fluid connection with the pressure inlet port. The bypass assembly includes a bypass housing, a pressure chamber, a piston with a first piston position and a second piston position, and a spring assembly. A pressure differential created by fluid flow through the pressure chamber and flow restrictor actuates the piston between the first piston position and the second piston position. The proportional flow through the tool assembly and through the bypass ports can now be controlled to perform the downhole work, including drilling and hole cleaning.

Pressure activated proportional flow bypass tool assembly

An apparatus and system for generating pressure pulses for enhancing and completing a well bore within a pipe or coiled tubing operation including: a valve longitudinally and axially positioned within the center of a pulser section, a gearbox, and an impeller. The main fluid flow is interrupted by the main valve which is operated by a controlled pilot fluid stream. The pilot fluid stream is controlled by a determined rotation of a gearbox driven by an impeller located centrally and axially and connected to the gearbox. Most specifically, the system utilizes pulse technology to improve weight transfer in horizontal wells by modulating flow, pressure and weight on the bit. The system can be used to overcome coiled tubing (CT) drill out challenges by overcoming friction forces that impede the downhole reach.

Drill string applications tool

An apparatus, method, and system for generating pressure pulses in a drilling fluid flowing within coiled tubing assembly is described that includes; a flow throttling device longitudinally and axially positioned within the center of a main valve actuator assembly that allows main exit flow fluid to flow past a drive shaft and motor such that the pilot fluid and the main exit flow fluid causes one or more flow throttling devices to generate large, rapid controllable pulses. The pulses generated by the flow throttling device thereby allow transmission of well-developed signals easily distinguished from any noise resulting from other vibrations due to nearby equipment within the borehole or exterior to the borehole, or within the coiled tubing assembly wherein the signals also provide predetermined height, width and shape of the signals.

Controlled pressure pulser for coiled tubing applications

An apparatus and system for generating pressure pulses for enhancing and completing a well bore within a coiled tubing assembly including: a CT-MWD-FTD tool longitudinally and axially positioned within the center of a main valve assembly including a main valve. The drilling fluid is subsequently split into both an inlet main fluid stream and a pilot fluid stream, wherein the pilot fluid stream subsequently flows such that the pilot fluid recombines with the main flow stream to become a main exit fluid flow. The main exit fluid flow then proceeds toward a motor housing wherein one or more annular pressure sensors measure the pressure of fluid flow with sensors that send signals to a Digital Signal Processor (DSP) that controls flow throttling devices which generate controllable, large, rapid and measurable energy pulses.

Controlled pressure pulser for coiled tubing measurement while drilling applications

An apparatus, method, and system described for generating pressure pulses in drilling fluid utilizing a flow throttling device which includes a controllable pulser operating sequentially within a downhole assembly within a drill string of a drill pipe. The system includes drilling fluid, fluid flow, and fluid drilling pump which when combined creates fluid flow into a bore pipe annulus within the downhole assembly creating a base line bore pipe pressure wherein bore pipe pressure is sensed via a sensor and information is sent to a Digital Signal Processor (DSP) that interprets the information. The DSP also receives information from an annulus pressure sensor that senses drilling fluid pressure as it returns to the pump. The DSP recognizes pressure variation input from the annulus pressure sensor and bore pipe pressure sensor and detects pressure variation providing signals as data information to the DSP, determining required action to adjust pulser operation.

Controlled full flow pressure pulser for measurement while drilling (MWD) device

The present invention provides a drilling system that utilizes an integrated bottom hole assembly. The bottom hole assembly contains sensors for determining the health of the bottom hole assembly, borehole condition, formation evaluation characteristics, drilling fluid physical and chemical properties, bed boundary conditions around and in front of the drill bit, seismic maps and the desired drilling parameters that include the weight on bit, drill bit speed and the fluid flow rate. A downhole processor controls the operation of the various devices in the bottom hole assembly to effect changes to the drilling parameters and the drilling direction to optimize the drilling effectiveness.

Growing community of inventors

Houston, TX, United States of America

Robert Paul MacDonald