Pangaea Enterprises, Inc.

Ccore Technology and Licensing, Ltd.

Innotech Energy Corporation

Ccore Technology & Licensing Limited, a Texas Limited Partnership

Harry B Curlett

George M Raulins

A drill bit with a housing and roller cones has a high-speed fluid jet erosion system utilizing dual discharge, high-velocity, jet streams that is directed at the surface to be eroded. The jet streams are developed from a dual discharge nozzle adapted to form a first, swirling liquid jet and a second, axial liquid jet in combination therewith. When used in a shale-like formation, the bit includes a nozzle in a bowl area of the housing that sends a vortex shaped spray against the roller cones.

Axial-vortex jet drilling system and method

A high-speed fluid/mechanical jet erosion system utilizing a high-velocity, jet stream discharged contiguous the surface to be cut. The jet stream is developed from a single plenum flow system adapted to merge and enhance the erosive high-speed fluid jet characteristics of fluid with cavitational collapse erosion. The system further includes a tapered drill bit housing, with mechanical cutters therealong which places a generally axially centered, exiting jet immediately against the target formation, providing maximum mechanical and fluid energy transfer to the formation.

Method of and apparatus for single plenum jet cutting

A high-speed fluid/mechanical Jet erosion system utilizing a high-velocity, spinning jet stream discharged contiguous the surface to be cut. The spinning jet stream is developed from a tangentially driven vortex flow system adapted to merge and enhance the erosive high-speed fluid jet characteristics of fluid and abrasive particle impingement erosion with cavitational collapse erosion in both axial and tangential directions. The system further includes an apertured mechanical cutting element which places the exiting spinning jet immediately against the target formation, providing maximum mechanical and fluid energy transfer to the formation. In this manner, the system induces formation fracturing by assisting mechanically induced fracture propagation with the high-speed jet action while simultaneously exploiting high-speed jet erosion-induced kerfs with the mechanical action of the tool.

Method and apparatus for jet cutting

A high-speed fluid/mechanical jet erosion system utilizing a high-velocity, spinning jet stream discharged contiguous the surface to be cut. The spinning jet stream is developed from a tangentially driven vortex flow system adapted to merge and enhance the erosive high-speed fluid jet characteristics of fluid and abrasive particle impingement erosion with cavitational collapse erosion in both axial and tangential directions. The system further includes an apertured mechanical cutting element which places the exiting spinning jet immediately against the target formation, providing maximum mechanical and fluid energy transfer to the formation. In this manner, the system induces formation fracturing by assisting mechanically induced fracture propagation with the high-speed jet action while simultaneously exploiting high-speed jet erosion-induced kerfs with the mechanical action of the tool.

Method of an apparatus for jet cutting

A multi-conduit tubular having fluid conduits (30) and electrical conduits (108), with associated surface fluid (182) and electrical (186) commutators, and downhole sensors (18, 20, 290) for providing surface monitors (22) with instantaneous formation data. Each tubular (50) includes a plurality of uniform linear conduits (30) therethrough, with a gasketed seal plate (86) interposed between joined tubulars for assuring a high pressure seal between joined conduits. The seal plate (86) includes an intermediate electrical connector (126) for connecting electrical conduit connectors (116) of one tubular to another. A coupling collar (84) with uniform diameter internal coarse and fine threads (92, 94) joins the tubular ends having similar threads by differential thread action without respective tubular rotation. Each tubular end further includes an interengaging index recess and index lug (106, 104), and drive recesses and lugs (102, 100) for maintaining angular registry of the tubular string and for driving one drill tubular with another. A fluid commutator (182) includes a rotating shaft with passages (204, 206) connected to the tubular conduits, and rotating in a manifold (198) having annular grooves (234, 236) in communication with the shaft passages (204, 206) and external fluid sources. An adaptor (184) couples each commutator shaft passage (204, 206) to one or more tubular conduits. Slip rings (264-270) on a quill shaft (178) and stationary brush means (272-278) provide electrical continuity from the electrical conduit wires (110) to surface equipment. A cross-over sub (286) includes formation parameter sensors (18, 20, 290) and telemetry equipment (292) in a blocked off portion of a fluid conduit. An annular accumulator (46) connected with the wellbore annulus (44) applies a pressure thereto in response to downhole sensors to change the effective density of the drill mud. The multi-conduit tubular (366) is further adapted for use as a well casing to provide downhole access of a plurality of fluids and electrical parameter sensors (424).

Drill pipes and casings utilizing multi-conduit tubulars

An improved drill pipe utilizing multi-conduit tubulars is provided. A seal subassembly (644) is constructed and arranged so as to receive a plurality of similar tubular conduits (626, 630). The similar tubular conduits (626, 630) are inserted into both ends of the seal subassembly (644). At one end, the tubular conduits (630) are threadably attached to the seal subassembly (644), while at the opposite end, the tubular conduits (626) are slidably attached to the seal subassembly (644). T-rings seals (674) are provided to insure sealing engagement of the tubular conduits to the seal subassembly (644). A collar (638) is provided to join a drill pipe (596) to one end of the seal subassembly (644). A lift subassembly (682) is provided to attach the other end of the seal subassembly (644) to another drill pipe (598). The seal subassembly (644) is constructed so as to allow the tubular conduits to be of strength sufficient to withstand pressure and compression forces only. Tension and torsional forces are handled entirely by the drill pipe outer casings (614, 616), the collar (638), the seal subassembly (644), and the lift subassembly (682).

A multi-conduit tubular having fluid conduits (30) and electrical conduits (108), with associated surface fluid (182) and electrical (186) commutators, and downhole sensors (18, 20, 290) for providing surface monitors (22) with instantaneous formation data. Each tubular (50) includes a plurality of uniform linear conduits (30) therethrough, with a gasketed seal plate (86) interposed between joined tubulars for assuring a high pressure seal between joined conduits. The seal plate (86) includes an intermediate electrical connector (126) for connecting electrical conduit connectors (116) of one tubular to another. A coupling collar (84) with uniform diameter internal coarse and fine threads (92, 94) joins the tubular ends having similar threads by differential thread action without respective tubular rotation. Each tubular end further includes an interengaging index recess and index lug (106, 104), and drive recesses and lugs (102, 100) for maintaining angular registry of the tubular string and for driving one drill tubular with another. A fluid commutator (182) includes a rotating shaft with passages (204, 206) connected to the tubular conduits, and rotating in a manifold (198) having annular grooves (234, 236) in communication with the shaft passages (204, 205) and external fluid sources. An adaptor (184) couples each commutator shaft passage (204, 206) to one or more tubular conduits. Slip rings (264-270) on a quill shaft (178) and stationary brush means (272-278) provide electrical continuity from the electrical conduit wires (110) to surface equipment. A cross-over sub (286) includes formation parameter sensors (18, 20, 290) and telemetry equipment (292) in a blocked off portion of a fluid conduit. An annular accumulator (46) connected with the wellbore annulus (44) applies a pressure thereto in response to downhole sensors to change the effective density of the drill mud. The multi-conduit tubular (366) is further adapted for use as a well casing to provide downhole access of a plurality of fluids and electrical parameter sensors (424).

Apparatus for coupling multi-conduit drill pipes to maintain arcuate registry between connected pipes, and for transferring the drive torque of one drill pipe to the next drill pipe. One end of one drill pipe (50) includes drive lugs (100) matable with corresponding drive recesses (102) in the end of the next drill pipe (52). An index lug (104) in the drill pipe end, different that the drive lugs (100), is matable with a corresponding index recess (106) in another pipe end ot maintain arcuate registry of the coupled pipes and thus longitudinal alignment of the respective conduits (30) throughout the drill string. An internally threaded coupling collar (84) with different thread pitches at each end thereof is threadable onto the joined lug and recess mated drill pipe ends to hold the pipes mated. The joined pipe ends respectively include external threads (88, 90) of pitches corresponding to that of the coupling collar (84) so that a differential thread action draws the pipes together. A seal (86) is provided between the pipe ends so that when compressed by rotation of the coupling collar (84) each conduit (30, 62) is sealed from adjacent conduits.

Growing community of inventors

Dallas, TX, United States of America

Harry B Curlett