Abstract: A rotary multiport greasing valve having an outer sleeve and an inner sleeve within the outer sleeve. The outer sleeve has at least one inlet port and at least 2 outlet ports. The inner sleeve has an inlet port, a central passageway, and an outlet port. The inner sleeves inlet port is fluidly connected to the outer sleeve's inlet port. The inner sleeve rotates within the outer sleeve so that the inner sleeves outlet port is circumferentially aligned with a selected outer sleeve outlet port creating a fluid pathway from the outer sleeve inlet port into the inner sleeve's inlet port through the central passageway through the inner sleeve's outlet port and finally through the outer sleeves outlet port to create an open flowpath. In certain instances, the inner sleeve inlet port is longitudinally shifted so as not to align with any portion of an outlet sleeve outlet port.

Abstract: A rotary multiport greasing valve having an outer sleeve and an inner sleeve within the outer sleeve. The outer sleeve has at least one inlet port and at least 2 outlet ports. The inner sleeve has an inlet port, a central passageway, and an outlet port. The inner sleeves inlet port is fluidly connected to the outer sleeve's inlet port. The inner sleeve rotates within the outer sleeve so that the inner sleeves outlet port is circumferentially aligned with a selected outer sleeve outlet port creating a fluid pathway from the outer sleeve inlet port into the inner sleeve's inlet port through the central passageway through the inner sleeve's outlet port and finally through the outer sleeves outlet port to create an open flowpath. In certain instances, the inner sleeve inlet port is longitudinally shifted so as not to align with any portion of an outlet sleeve outlet port.

Abstract: An isolation tool is provided that includes an upper elastomer, a lower elastomer. The isolation tool when set provides a circumferential flow path between the elastomers. The isolation tool also includes a longitudinal flow path from above the isolation tool to below the isolation tool. The longitudinal flowpath is preferably sufficiently linear that a solid tool may be passed through the longitudinal flowpath from above the isolation tool to below the isolation tool.

Abstract: An isolation tool is provided that includes an upper elastomer, a lower elastomer. The isolation tool when set provides a circumferential flow path between the elastomers. The isolation tool also includes a longitudinal flow path from above the isolation tool to below the isolation tool. The longitudinal flowpath is preferably sufficiently linear that a solid tool may be passed through the longitudinal flowpath from above the isolation tool to below the isolation tool.

Abstract: A system to provide at least two circumferential metal to metal seals between coaxial tubulars. Where a first tubular includes a circumferential shoulder having a circumferential first metal seal and a circumferential second metal seal. A second tubular has a circumferential shoulder that matches and abuts the first tubular circumferential shoulder. Each metal seal is of a material having a higher yield strength than the second tubular shoulder such that the first metal seal and the second metal seal will penetrate the material of the second tubular shoulder thereby providing a seal. Additionally a test port is provided from the exterior of the exterior tubular to a point on either the first or second tubular between the first and second metal seals.

Abstract: An inwardly biased tubing hanger is provided that allows for continued turns in the same direction to both lock the tubing hanger in place within the well as well as release the running tool from the tubing hanger. An energizing sleeve and running tool each having left hand threads is provided where a torque ring between the energizing sleeve and running tool allows the running tool to be turn in the right hand direction until sufficient torque is provided to the torque sleeve to release the running tool from the energizing sleeve. With the running tool attached to the energizing sleeve the energizing sleeve provides sufficient force, provided the torque limit of the torque sleeve is not been reached, to drive the inwardly biased torque ring radially outward.

Abstract: A greasing system may be placed partially within the red zone and partially outside of the red zone. Grease and pneumatic power is supplied from outside of the red zone to a pod, inside of the red zone, having local storage, high-pressure pumping capacity, and a distribution mechanism. The grease is supplied from outside of the red zone to the pod at low-pressure through a hose having at least a 1 inch inside diameter and is usually at least 100 feet long. The pod pressurizes the grease to a high-pressure and distributes the grease via a distribution mechanism to a relatively short hose, generally less than 8 feet between the distribution mechanism and the greasing point on the wellhead, in order to minimize pressure losses.

Abstract: A rotary multiport greasing valve having an outer sleeve and an inner sleeve within the outer sleeve. The outer sleeve has at least one inlet port and at least 2 outlet ports. The inner sleeve has an inlet port, a central passageway, and an outlet port. The inner sleeves inlet port is fluidly connected to the outer sleeve's inlet port. The inner sleeve rotates within the outer sleeve so that the inner sleeves outlet port is circumferentially aligned with a selected outer sleeve outlet port creating a fluid pathway from the outer sleeve inlet port into the inner sleeve's inlet port through the central passageway through the inner sleeves outlet port and finally through the outer sleeves outlet port to create an open flowpath. In the instance where a closed flowpath is desired the inner sleeve inlet port is rotated so as not to align with any portion of an outlet sleeve outlet port.

Abstract: A hydraulic accumulator system is provided to remove the motors or engines from the red zone while maintaining sufficient capacity within the red zone to quickly close the designated blowout preventer or other gate valves. Additionally, a single point is provided outside of the red zone to charge the local storage units or to open or close the designated blowout preventer or other gate valves when time is not a critical consideration.

Abstract: A wellhead is provided having a port or ports about the external periphery of the wellhead. The center bore of each port is generally directed at a point within the wellhead having a location where a portion of a tool or an object is expected. Each port does not provide fluid access from the exterior to the interior of the wellhead and preferably has a flat bottom. Each port is fitted with a sensor and preferably the sensor contacts the bottom of the port. And ultrasonic a sensor emits an ultrasonic waveform which proceeds through the bottom of the port and a portion of the ultrasonic waveform is reflected back to the ultrasonic receiver. A comparison is then performed to compare the predicted value versus the received value to determine whether or not the expected tool or object is in place or partially in place within the wellhead.

Abstract: A sensor system to indicate whether or not the gate valve is open, closed, or at some position between. In certain instances, two sensors may be used to indicate the position of an attachment to the gate within the gate valve thereby indicating whether or not the gate within the gate valve is fully opened or fully closed. In other instances, a single sensor may be utilized to indicate the position of an attachment to the gate within the gate valve such position being between and including fully opened and fully closed. Generally, a sensor which may include both an emitter and receiver, is affixed externally of the pressurized portion of the gate valve or other type of valves.

Abstract: A sensor system to prevent the unintended severing or damage to a cable or other object within the throughbore of a standpipe or wellhead that may include a blowout preventer and gate valves. Generally, a sensor which may include both an emitter and receiver, is affixed externally to the standpipe, wellhead, blowout preventer, or gate valves. None of the emitter or receiver penetrates the pressure vessel formed by the standpipe, wellhead, blowout preventer, or gate valves. The sensor system may detect disturbances in a pre-existing field such as a geomagnetic sensor detecting the earth's magnetic field, the sensor may create a field and then detect disturbances within that created field such as a magnetic sensor, or the sensor may send a pulse of energy towards the area to be sensed and then read the reflected energy. Generally, the sensor system includes a logic controller, a memory, a sensor or sensors that may or may not include emitters and receivers, and a display.

Abstract: An inwardly biased tubing hanger is provided that allows for continued turns in the same direction to both lock the tubing hanger in place within the well as well as release the running tool from the tubing hanger. An energizing sleeve and running tool each having left hand threads is provided where a torque ring between the energizing sleeve and running tool allows the running tool to be turn in the right hand direction until sufficient torque is provided to the torque sleeve to release the running tool from the energizing sleeve. With the running tool attached to the energizing sleeve the energizing sleeve provides sufficient force, provided the torque limit of the torque sleeve is not been reached, to drive the inwardly biased torque ring radially outward.

Abstract: A system to provide at least two circumferential metal to metal seals between coaxial tubulars. Where a first tubular includes a circumferential shoulder having a circumferential first metal seal and a circumferential second metal seal. A second tubular has a circumferential shoulder that matches and abuts the first tubular circumferential shoulder. Each metal seal is of a material having a higher yield strength than the second tubular shoulder such that the first metal seal and the second metal seal will penetrate the material of the second tubular shoulder thereby providing a seal. Additionally a test port is provided from the exterior of the exterior tubular to a point on either the first or second tubular between the first and second metal seals.

Abstract: To deploy a capillary string through a wellhead to a downhole safety valve, a control port and a retention port are drilled in an adapter between a casing hanger and a gate valve or elsewhere. The capillary string is connected to a first port of a capillary hanger and installed through the wellhead. The capillary hanger is landed on a tubing hanger, and a side port on the capillary hanger communicates with the control port. Because the side port's location may not align with the control port, operators may need to measure how long the capillary hanger should be. A control line connects to the control port in the wellhead's side to communicate with the capillary line, and a retention rod inserts in the retention port to support the capillary hanger.

Abstract: To deploy a capillary string through a wellhead to a downhole safety valve, a control port and a retention port are drilled in an adapter between a casing hanger and a gate valve or elsewhere. The capillary string is connected to a first port of a capillary hanger and installed through the wellhead. The capillary hanger is landed on a tubing hanger, and a side port on the capillary hanger communicates with the control port. Because the side port's location may not align with the control port, operators may need to measure how long the capillary hanger should be. A control line connects to the control port in the wellhead's side to communicate with the capillary line, and a retention rod inserts in the retention port to support the capillary hanger.

Abstract: To deploy a capillary string through a wellhead to a downhole safety valve, a control port and a retention port are drilled in an adapter between a casing hanger and a gate valve or elsewhere. The capillary string is connected to a first port of a capillary hanger and installed through the wellhead. The capillary hanger is landed on a tubing hanger, and a side port on the capillary hanger communicates with the control port. Because the side port's location may not align with the control port, operators may need to measure how long the capillary hanger should be. A control line connects to the control port in the wellhead's side to communicate with the capillary line, and a retention rod inserts in the retention port to support the capillary hanger.

Abstract: To deploy a capillary string through a wellhead to a downhole safety valve, a control port and a retention port are drilled in an adapter between a casing hanger and a gate valve or elsewhere. The capillary string is connected to a first port of a capillary hanger and installed through the wellhead. The capillary hanger is landed on a tubing hanger, and a side port on the capillary hanger communicates with the control port. Because the side port's location may not align with the control port, operators may need to measure how long the capillary hanger should be. A control line connects to the control port in the wellhead's side to communicate with the capillary line, and a retention rod inserts in the retention port to support the capillary hanger.

Abstract: To deploy a capillary string through a wellhead to a downhole safety valve, a control port and a retention port are drilled in an adapter between a casing hanger and a gate valve or elsewhere. The capillary string is connected to a first port of a capillary hanger and installed through the wellhead. The capillary hanger is landed on a tubing hanger, and a side port on the capillary hanger communicates with the control port. Because the side port's location may not align with the control port, operators may need to measure how long the capillary hanger should be. A control line connects to the control port in the wellhead's side to communicate with the capillary line, and a retention rod inserts in the retention port to support the capillary hanger.

Abstract: A semi-automatic speech transcription system of the invention leverages the complementary capabilities of human and machine, building a system which combines automatic and manual approaches. With the invention, collected audio data is automatically distilled into speech segments, using signal processing and pattern recognition algorithms. The detected speech segments are presented to a human transcriber using a transcription tool with a streamlined transcription interface, requiring the transcriber to simply “listen and type”. This eliminates the need to manually navigate the audio, coupling the human effort to the amount of speech, rather than the amount of audio. Errors produced by the automatic system can be quickly identified by the human transcriber, which are used to improve the automatic system performance. The automatic system is tuned to maximize the human transcriber efficiency.