Disclosed herein are various embodiments of an Annular Pressure Control Ram Diverter designed to be positioned below the conventional blowout preventer stack, and which will be activated during near balanced drilling operations to seal the annulus between the drill pipe and the casing. Returned drilling fluid and produced fluids are diverted up the annulus between the casing and intermediate casing and through a well head located below an all-inclusive BOP stack. The Annular Pressure Control Ram Diverter employs hydraulic rams to compress a flexible seal around the drill pipe. Some embodiments have an elliptical internal cavity which ensures that the elliptical seal elements cannot rotate. Other embodiments use ridges and grooves on the seal elements and housing to prevent rotation of the seal elements. Doors are provided on each side of the Annular Pressure Control Ram Diverter to permit changing of the seal elements.
Disclosed herein are various embodiments of well control system for drilling an oil or gas well safely and efficiently by providing a mechanical actuator capable of transmitting a rotational force downhole, and converting the rotational force to an axial force for the purpose of operating downhole equipment, including subsurface safety valves, compressible bladder valves, and sliding sleeve valves. Because the actuator is mechanical and not hydraulic as in conventional equipment, the force applied is independent of the depth at which it is applied, overcoming a major deficiency seen in comparable hydraulic systems.
Disclosed herein are various embodiments of a method for minimizing formation damage while drilling an oil or gas well. An Annular Pressure Control Diverter is designed to be positioned below the conventional blowout preventer stack, and is activated during near balanced drilling operations to seal the annulus between the drill pipe and the production casing. Returned drilling fluid and produced fluids are diverted up the annulus between the production casing and intermediate casing and through a well head located below an all-inclusive BOP stack. The seal elements within the Annular Pressure Control Diverter do not rotate. Doors are provided on each side of the Annular Pressure Control Diverter to permit changing of the seal elements. The Annular Pressure Control Diverter also is used to ensure the capture of methane while drilling in a hydrocarbon bearing reservoir.
Disclosed herein are various embodiments of an Annular Pressure Control Diverter designed to be positioned below the conventional blowout preventer stack, and which will be activated during near balanced drilling operations to seal the annulus between the drill pipe and the production casing. Returned drilling fluid and produced fluids are diverted up the annulus between the production casing and intermediate casing and through a well head located below an all-inclusive BOP stack. The Annular Pressure Control Diverter does not rotate, and some embodiments have an elliptical internal cavity which ensures that the elliptical seals cannot rotate. Doors are provided on each side of the Annular Pressure Control Diverter to permit changing of the seal elements. Door locking mechanisms are provided for operator safety.
Disclosed herein are various embodiments of methods and systems for drilling a wellbore into an oil or gas production zone to prevent formation damage in the reservoir using underbalanced or near-balanced drilling techniques, wherein a jet pump drilling assembly is used to create a vacuum around the drill bit. The design of this jet pump drilling assembly prevents the flow of all drilling/power fluid from entering a drill bit Only fluids from the reservoir are allowed to enter the drill bit. The assembly includes a barrier to ensure that no drilling/power fluid discharged from the jet pump located above the drill bit can flow back around to the jet pump jet pump suction ports located in the drill bit thus preventing any drilling/power fluid from ever contacting the drill bit.
Disclosed herein are various embodiments of methods and systems for drilling a wellbore into an oil or gas production zone to prevent formation damage in the reservoir using underbalanced or near-balanced drilling techniques, wherein a jet pump drilling assembly is used to create a vacuum around the drill bit. The design of this jet pump drilling assembly prevents the flow of all drilling/power fluid from entering a drill bit Only fluids from the reservoir are allowed to enter the drill bit. The assembly includes a barrier to ensure that no drilling/power fluid discharged from the jet pump located above the drill bit can flow back around to the jet pump jet pump suction ports located in the drill bit thus preventing any drilling/power fluid from ever contacting the drill bit.
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
E21B 21/12 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor using drilling pipes with plural fluid passages, e.g. closed circulation systems
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
Disclosed are methods for drilling an oil or gas well safely and efficiently using underbalanced or near-balanced drilling techniques, wherein the primary means of pressure control is an Annular Pressure Control Diverter positioned below the conventional blowout preventer stack, with a return flow pattern where no drilling fluid returns up the (traditional) annulus between the drill pipe and the production casing and instead drilling fluid returns up the annulus between the production casing and intermediate casing. Drilling fluid returns flow through a wellhead, instead of a flow spool conventionally located just below an upper RCD, the wellhead being located below an all-inclusive BOP stack, and hence to the drilling choke. This drilling approach eliminates the need for hydraulic fracturing and preserves the natural fracture system of the producing formation while providing additional safety measures. It also prevents the accidental discharge or flaring of methane during drilling and production.
Disclosed herein are various embodiments of methods and systems for drilling an oil or gas well safely and efficiently using underbalanced or near-balanced drilling techniques, wherein the primary means of pressure control is a Annular Pressure Control Diverter positioned below the BOP stack, with a return flow pattern where no drilling fluid returns up the (traditional) annulus between the drill pipe and the production casing and instead drilling fluid returns up the annulus between the production casing and intermediate casing. Drilling fluid returns flow through a wellhead, instead of a flow spool conventionally located below an upper RCD, and hence to the drilling choke. This drilling approach eliminates the need for hydraulic fracturing and preserves the natural fracture system of the producing formation while providing additional safety measures. It also prevents the accidental or deliberate discharge or flaring of methane during drilling and production.
A tool joint connection includes a first tool joint and a second tool joint. The first tool joint has a male connector portion with a lobed polygonal profile extending longitudinally from one end of the first tool joint toward an opposing end thereof. The second tool joint has a female connector portion having a lobed polygonal profile extending longitudinally from one end of the second tool joint toward an opposing end thereof. The lobed polygonal profile of the male connector portion corresponds to the lobed polygonal profile of the female so the male connector portion of the first tool joint is non-rotatably receivable in the female connector portion of the second tool joint to form a connection between the first tool joint and the second tool joint.
F16L 25/01 - Construction or details of pipe joints not provided for in, or of interest apart from, groups specially adapted for realising electrical conduction between the two pipe ends of the joint or between parts thereof
B29C 65/00 - Joining of preformed partsApparatus therefor
H01R 13/52 - Dustproof, splashproof, drip-proof, waterproof, or flameproof cases
B29C 65/34 - Joining of preformed partsApparatus therefor by heating, with or without pressure using heated elements which remain in the joint, e.g. "verlorenes Schweisselement"
A tool joint connection includes a first tool joint and a second tool joint. The first tool joint has a male connector portion with a lobed polygonal profile extending longitudinally from one end of the first tool joint toward an opposing end thereof. The second tool joint has a female connector portion having a lobed polygonal profile extending longitudinally from one end of the second tool joint toward an opposing end thereof. The lobed polygonal profile of the male connector portion corresponds to the lobed polygonal profile of the female so the male connector portion of the first tool joint is non-rotatably receivable in the female connector portion of the second tool joint to form a connection between the first tool joint and the second tool joint.
A tool joint connection includes a first tool joint and a second tool joint. The first tool joint has a male connector portion with a lobed polygonal profile extending longitudinally from one end of the first tool joint toward an opposing end thereof. The second tool joint has a female connector portion having a lobed polygonal profile extending longitudinally from one end of the second tool joint toward an opposing end thereof. The lobed polygonal profile of the male connector portion corresponds to the lobed polygonal profile of the female so the male connector portion of the first tool joint is non-rotatably receivable in the female connector portion of the second tool joint to form a connection between the first tool joint and the second tool joint.
An electric submersible hydraulic lift pump system is used for removing fluid from a well. The hydraulic lift pump system includes a source of fluid, a tubing string extending from the surface and in fluid communication with the source of fluid, a first pump interposed in the tubing string so the first pump is positioned below the surface and operably arranged to draw fluid from the tubing string upstream of the first pump and to discharge the fluid into the tubing string downstream of the first pump as a power fluid, and a second pump interposed in the tubing string and operably arranged to receive the power fluid from the first pump and be combined with a production fluid to form a return fluid to be discharged into the annulus.
An electric submersible hydraulic lift pump system is used for removing fluid from a well. The hydraulic lift pump system includes a source of fluid, a tubing string extending from the surface and in fluid communication with the source of fluid, a first pump interposed in the tubing string so the first pump is positioned below the surface and operably arranged to draw fluid from the tubing string upstream of the first pump and to discharge the fluid into the tubing string downstream of the first pump as a power fluid, and a second pump interposed in the tubing string and operably arranged to receive the power fluid from the first pump and be combined with a production fluid to form a return fluid to be discharged into the annulus.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
F04B 47/06 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having motor-pump units situated at great depth
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