Abstract: A microvalve comprising a hard base 14, a clamping plate 12, an inlet port 96, 98, an outlet port 96, 98, a membrane 16, a ball bearing 18 and a drive head 20; wherein the hard base comprises a recess over which the membrane is clamped by the clamping plate, the recess defining a cup with a generally spherical cap shaped surface and a perimeter, both of the inlet and outlet ports being in the recess, and at least one of them being in the generally spherical cap shaped surface; wherein the membrane extends across the recess and is clamped thereover, and it is flexible for enabling the unclamped part of it to be flexed into the recess by the ball bearing in the clamping plate on the other side of the membrane to the recess upon actuation by the drive head behind the ball bearing for selective driving of the ball bearing against the membrane to flex the membrane into the recess as the membrane flexes around part of the ball bearing to move the membrane from a condition in which both ports are open to a port clo

Abstract: 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.

Abstract: A fluid transfer device can include a first attachment portion configured to engage a first port of a source container and a second attachment portion configured to engage a second port of an intermediate container. The first attachment portion can include a first projection defining a first fluid passage and the second attachment portion can include a second projection defining a second fluid passage. The fluid transfer device can further include a selector portion for selectively transitioning the fluid transfer device from a first configuration in which a flow path between the first and second fluid passages is closed to a second configuration in which the flow path between the first and second fluid passages is open. The fluid transfer device can further include a limiter configured to inhibit the selector portion from selectively transitioning the fluid transfer device from the first configuration to the second configuration.

Abstract: 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 is a ram operated device, wherein hydraulic rams compress a flexible seal around the drill pipe. 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 Ram Diverter to permit changing of the seal elements.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: The subject invention pertains to a method and apparatus for an orientation independent compressor. The subject compressor can be part of a vapor compression cycle system, and can use one or more of a variety of working fluids, including, but not limited to, refrigerants such as r-134a, r-22, CO2, and NH3. Embodiments of the compressor can utilize positive displacement apparatus to compress the vapor. In a specific embodiment, the compressor can incorporate an oil-lubricated rotary lobed type positive displacement compressor. In a further specific embodiment, the working fluid vapor can be a refrigerant, such as r-134a, incorporating entrained oil, such as miscible lubricating oils. An example of such a miscible lubricating oil that can be used is polyester (POE) oil.

Abstract: 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.

Abstract: 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.

Abstract: The present disclosure provides methods and systems for generating biological tissues that are configured for folding into a pre-determined three-dimensional form. The present disclosure utilizes contractile cells for folding a biological tissue into a three-dimensional shape. The methods include disposing a pattern of contractile cells on a surface that includes fibers actuated by the contractile cells and folding of the surface by the action of the contractile cells on the fibers. Tissues generated using the methods and systems of the present disclosure are also provided.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: The present disclosure provides methods and systems for generating biological tissues that are configured for folding into a pre-determined three-dimensional form. The present disclosure utilizes contractile cells for folding a biological tissue into a three-dimensional shape. The methods include disposing a pattern of contractile cells on a surface that includes fibers actuated by the contractile cells and folding of the surface by the action of the contractile cells on the fibers. Tissues generated using the methods and systems of the present disclosure are also provided.

Abstract: Methods, apparatus and systems are disclosed for managing digitally-streamed audio communication sessions between user devices (7a, 7b, 7c). The user devices are configured to send digitally-streamed data (21) indicative of received audio contributions from respective participants in a multiple-participant audio communication session to a multiple-participant audio communication session controller (30) for processing and onward streaming of data (22) indicative of the received audio contributions from the session controller (30) to one or more other user devices (7a, 7b, 7c) for conversion to audio representations for respective other participants of the received audio contributions. The data (21, 22) is streamed between the session controller and the respective user devices in accordance with one or more digital streaming profiles having one or more adjustable digital streaming parameters.

Abstract: Methods, apparatus and systems are disclosed for managing digitally-streamed audio communication sessions between user devices (7a, 7b, 7c). The user devices are configured to send digitally-streamed data (21) indicative of received audio contributions from respective participants in a multiple-participant audio communication session to a multiple-participant audio communication session controller (30) for processing and onward streaming of data (22) indicative of the received audio contributions from the session controller (30) to one or more other user devices (7a, 7b, 7c) for conversion to audio representations for respective other participants of the received audio contributions. The data (22) streamed from the session controller to the respective user devices has one or more audio parameters affecting the audio representations provided by the user devices to the participants using them.

Abstract: Electrophoretic separation devices and methods for using the same are provided. Aspects of the devices include a polymeric separation medium that includes a plurality of microwells. Also provided are methods, systems and kits in which the subject devices find use. The devices and methods find use in a variety of different electrophoretic separation applications.