Abstract: Processes and systems for drilling a borehole wherein a gravitational energy term, a torsional energy term, a hydraulic energy term and a hydromechanical specific energy which is the sum thereof may be determined using real-time data and compared against corresponding setpoints. The hydraulic energy term may include a hydraulic energy reduction factor so as to account for the distance between the fluid nozzle of the drill bit and the rock and may include the kinematic viscosity of drilling fluid. One or more drilling parameters, such as weight on bit, revolutions per minute, drilling fluid flow rate, or combinations thereof, may be adjusted based upon such comparison to approximate the least amount of energy required to destroy and remove a given unit volume of rock. The setpoints may be changed manually or automatically at the direction of the user.

Abstract: An electromagnetic induction generator for use in a tubular, such as a tubular deployed in a subterranean well during wellbore construction operations, for generating electric current through electromagnetic induction. The electromagnetic induction generator has at least one conductive coil and at least one Halbach array of magnets. One or both of the at least one conductive coil and the at least one Halbach array of magnets is rotated relative to the other to increase the electric current generated. One or more gears may be provided to multiply the generated electric current.

Abstract: A dedicated hydraulic line for transmission of a signal device capable of generating one or more unique signals to one or more tools within a subterranean well. Each tool can be equipped with a reader device for receiving signals from and transmitting signals to the signal device. Each reader device can control operation of the tool associated therewith if the reader device is programmed to respond to signals received from the control device. Hydraulic fluid used to operate the tool can be conveyed via the dedicated hydraulic line or a separate hydraulic line. A separate hydraulic line can be used to reset the tool.

Abstract: A dedicated hydraulic line for transmission of a signal device capable of generating one or more unique signals to one or more tools within a subterranean well. Each tool can be equipped with a reader device for receiving signals from and transmitting signals to the signal device. Each reader device can control operation of the tool associated therewith if the reader device is programmed to respond to signals received from the control device. Hydraulic fluid used to operate the tool can be conveyed via the dedicated hydraulic line or a separate hydraulic line. A separate hydraulic line can be used to reset the tool.

Abstract: A method and apparatus for determining position in a pipe provides for the precise determination of location and associated characteristics of each pipe joint of a well, cross country pipeline or other fluid transmission line. The system includes a passive or active radio identification device at each joint in the pipe or casing string. The devices are preferably sealed within the resilient seal positioned between each pipe or casing joint. A pipeline tool includes a radio transmitter and receiver, with the transmitter transmitting on a frequency selected for resonating the identification devices. The resonant response of each device is detected by a receiver in the pipeline tool, with the response transmitted to the surface via the wireline to which the tool is connected. Alternatively, the tool may include storage information means until the tool can be recovered from the well or pipe.

Abstract: Processes and systems for logging production of fluid produced into a well bore without intervention of the well are disclosed. Two or more markers may be introduced into produced fluid at spaced apart locations along a well. The time for each marker to reach a common point may be measured and production rates for produced fluids at each spaced apart location may be calculated.

Abstract: Processes and systems for fracturing a formation are disclosed. Tools that may be selectively opened and closed are positioned on a tubular liner that in turn is positioned within a subterranean well bore. Separate pairs of packers are also attached to and positioned along the tubular liner so as to straddle each tool. Fracturing fluid is pumped from the surface through the tubular and open tool and past a pair of packers at a temperature and injection rate which causes contraction of the tubular liner. Thereafter, the velocity of the fracturing fluid is sufficient to set the pair of packers adjacent the open tool. Continued pumping of fracturing fluid is directed by the set packers into the adjacent subterranean environs at a pressure sufficient to fracture the subterranean environs.

Abstract: Processes and systems for drilling a borehole wherein a gravitational energy term, a torsional energy term, a hydraulic energy term and a hydromechanical specific energy which is the sum thereof may be determined using real-time data and compared against corresponding setpoints. The hydraulic energy term may include a hydraulic energy reduction factor so as to account for the distance between the fluid nozzle of the drill bit and the rock and may include the kinematic viscosity of drilling fluid. One or more drilling parameters, such as weight on bit, revolutions per minute, drilling fluid flow rate, or combinations thereof, may be adjusted based upon such comparison to approximate the least amount of energy required to destroy and remove a given unit volume of rock. The setpoints may be changed manually or automatically at the direction of the user.

Abstract: Apparatus, assembly and process for allowing gas lift operations to be conducted along a relatively long perforated interval below a packer in a generally vertical or a deviated subterranean well. An elongated segregation member may be lowered into locking engagement with a bypass mandrel secured to a tubing string above the packer. This segregation member may be configured and dimensioned to define two fluid flow paths. A first flow path extends from the surface of the earth through the annulus formed between the tubing string above the packer and casing secured in the well, the bypass mandrel, a bore through a portion of the segregation member and the interior of the tubing string below the packer. A second flow path extends from the subterranean region penetrated by the well through the annulus formed between the tubing string below the packer and casing secured in the well, the annulus between the segregation member and the packer, and the interior of the tubing string above the packer.

Abstract: Processes and systems for fracturing a formation are disclosed. Tools that may be selectively opened and closed are positioned on a tubular liner that in turn is positioned within a subterranean well bore. Separate pairs of packers are also attached to and positioned along the tubular liner so as to straddle each tool. Fracturing fluid is pumped from the surface through the tubular and open tool and past a pair of packers at a temperature and injection rate which causes contraction of the tubular liner. Thereafter, the velocity of the fracturing fluid is sufficient to set the pair of packers adjacent the open tool. Continued pumping of fracturing fluid is directed by the set packers into the adjacent subterranean environs at a pressure sufficient to fracture the subterranean environs.

Abstract: A method and apparatus for determining position in a pipe provides for the precise determination of location and associated characteristics of each pipe joint of a well, cross country pipeline or other fluid transmission line. The system includes a passive or active radio identification device at each joint in the pipe or casing string. The devices are preferably sealed within the resilient seal positioned between each pipe or casing joint. A pipeline tool includes a radio transmitter and receiver, with the transmitter transmitting on a frequency selected for resonating the identification devices. The resonant response of each device is detected by a receiver in the pipeline tool, with the response transmitted to the surface via the wireline to which the tool is connected. Alternatively, the tool may include storage information means until the tool can be recovered from the well or pipe.

Abstract: A gas separation or gas transportation process forms a gas hydrate from an aqueous feed and a gas feed having a hydrate P-T stability envelope. While in the presence of the aqueous feed, the gas feed is initially pressurized to an operating pressure and cooled to an operating temperature which are inside the hydrate P-T stability envelope to form a gas hydrate from at least a portion of the gas feed and at least a portion of the aqueous feed. The resulting gas hydrate is readily separable from any remaining gas and stable for transport.

Abstract: An assembly and process for identifying and tracking assets, such as tubulars, equipment, tools and/or devices. An antenna is electrically connected to a responding device, such as a radio frequency identification device, and this assembly is connected to an asset. The antenna may be positioned about the exterior and/or the interior of the asset and significantly increases the range of signals that may be received and/or broadcast by the responding device. A transceiver may accordingly be positioned a greater distance from the asset without regard to the orientation of the asset and still permit communication between the transceiver and the responding device. In this manner, information that specifically identifies the asset may be compiled in a data base so as to maintain an accurate history of the usage of such assets as tubulars, equipment, tool and/or devices.

Abstract: A method for performing operations and for improving production in a well includes the steps of: providing radio identification devices at known locations in the well, and providing a reader device configured to read the identification devices, and to control the operations responsive to signals from the identification devices. The method also includes the steps of providing a process tool, and transporting the process tool and the reader device through the well. The reader device is programmed to control the process tool upon reception of a response signal from a selected identification device. The method can be used to perform perforating processes, packer setting processes, bridge plug setting processes, logging processes, inspection processes, chemical treating processes, and cleaning processes. In addition, the method can be performed dynamically by controlling the tool as it moves through the well, or statically by stopping the tool at a particular location within the well.

Abstract: Processes and systems for logging production of fluid produced into a well bore without intervention of the well are disclosed. Two or more markers may be introduced into produced fluid at spaced apart locations along a well. The time for each marker to reach a common point may be measured and production rates for produced fluids at each spaced apart location may be calculated.

Abstract: A method and apparatus for actuating a downhole tool in a wellbore. The method and apparatus including an actuator that operates the tool in response to the functioning of an energetic charge. The energetic charge may be set off as a part of a perforating operation.

Abstract: A gas separation or gas transportation process forms a gas hydrate from an aqueous feed and a gas feed having a hydrate P-T stability envelope. While in the presence of the aqueous feed, the gas feed is initially pressurized to an operating pressure and cooled to an operating temperature which are inside the hydrate P-T stability envelope to form a gas hydrate from at least a portion of the gas feed and at least a portion of the aqueous feed. The resulting gas hydrate is readily separable from any remaining gas and stable for transport.

Abstract: Apparatus, assembly and process for allowing gas lift operations to be conducted along a relatively long perforated interval below a packer in a generally vertical or a deviated subterranean well. An elongated segregation member may be lowered into locking engagement with a bypass mandrel secured to a tubing string above the packer. This segregation member may be configured and dimensioned to define two fluid flow paths. A first flow path extends from the surface of the earth through the annulus formed between the tubing string above the packer and casing secured in the well, the bypass mandrel, a bore through a portion of the segregation member and the interior of the tubing string below the packer. A second flow path extends from the subterranean region penetrated by the well through the annulus formed between the tubing string below the packer and casing secured in the well, the annulus between the segregation member and the packer, and the interior of the tubing string above the packer.

Abstract: A method for performing operations and for improving production in a well includes the steps of: providing radio identification devices at known locations in the well, and providing a reader device configured to read the identification devices, and to control the operations responsive to signals from the identification devices. The method also includes the steps of providing a process tool, and transporting the process tool and the reader device through the well. The reader device is programmed to control the process tool upon reception of a response signal from a selected identification device. The method can be used to perform perforating processes, packer setting processes, bridge plug setting processes, logging processes, inspection processes, chemical treating processes, and cleaning processes. In addition, the method can be performed dynamically by controlling the tool as it moves through the well, or statically by stopping the tool at a particular location within the well.

Abstract: Apparatus, assembly and process for allowing gas lift operations to be conducted along a relatively long perforated interval below a packer in a subterranean well. An elongated segregation member is lowered into locking engagement with a bypass mandrel secured to a tubing string above the packer. This segregation member is configured and dimensioned to define two fluid flow paths. Fluid produced into the well from the subterranean region is conveyed to the surface via the second flow path and can be assisted by gas injected into the first flow path via retrievable gas lift valves in the tubing string above and below the packer. Pressurized gas is conveyed via the first flow path to these retrievable gas lift valves.