Abstract:
The present invention generally relates to a hydraulic communication device (10)that is used in a wellbore for fluid communication during a wellbore operation. In one aspect, a hydraulic communication device (10) is provided. The hydraulic communication device includes a body (30) having a central passageway (40) and a bore (55) formed in a wall of the body. The bore is in fluid communication with the central passageway, and the bore is configured to receive an end of a control line (25). The hydraulic communication device further includes a plug assembly (100) disposed in the bore formed in the wall of the body. The plug assembly is movable from a first position in which fluid communication through the bore is blocked and a second position in which fluid communication through the bore is unblocked.
Abstract:
A ball seat assembly includes a tubular having a bore therethrough; an entry port in fluid communication with the bore; a plurality of exit ports in fluid communication with the entry port; a ball seat disposed in the each of the plurality of exit ports, wherein the ball seat is configured to receive a ball to block fluid flow through the respective exit port; and a diverter configured to block fluid flow through the bore and direct fluid flow from the bore to the entry port.
Abstract:
A sliding sleeve (100) opens with a deployed ball (B). The sleeve has a seat (170) disposed in a bore of the inner sleeve and comprises a landing ring (172) disposed in the bore and being movable axially from a first axial position to a second axial position therein. A compressible ring (174) is also disposed in the bore and defines a space between a portion of the compressible ring and the bore. The landing ring in the first position supports the deployed ball with a first contact dimension and moves the inner sleeve to the opened position in response to application of first fluid pressure against the engaged ball. The landing ring moves from the first position to the second position in the inner sleeve when in the opened position in response to second fluid pressure applied against the engaged ball. The landing ring in the second position fits in the space between the compressible ring and the second bore and contracts the compressible ring inward. As a result, the segments moved inward support the engaged ball with a second contact dimension narrower than the first contact dimension.
Abstract:
A sliding sleeve opens with a deployed ball. The sleeve has a seat disposed in the housing, and the seat has segments biased outward from one another with a C-ring or other biasing element. Initially, the seat has an expanded state in the sliding sleeve so that the seats segments expand outward against the housing's bore. When an appropriately sized ball is deployed downhole, the ball engages the expanded seat. Fluid pressure applied against the seated ball moves the seat into the inner sleeve's bore. As this occurs, the seat contracts, which increases the engagement area of the seat with the ball. Eventually, the seat reaches the shoulder in the inner sleeve so that pressure applied against the seated ball now moves the inner sleeve in the housing to open the sliding sleeve's flow port.
Abstract:
A method of connecting a first threaded tubular to a second threaded tubular includes: engaging threads of the tubulars; and rotating the first tubular relative to the second tubular, thereby making up the threaded connection. The method further includes, during makeup of the threaded connection: measuring torque applied to the connection; measuring turns of the first tubular; and detecting a shoulder position. The method further includes: displaying the measured torque and turns; overlaying a reference curve onto the display; evaluating the threaded connection by comparing the measured torque and turns to the reference curve; and graphically displaying the evaluation.
Abstract:
A device and method to allow a sucker rod to be disconnected at a particular point in a sucker rod string (20). Typically the disconnect device (100) is located just above the barrel pump (32) where the disconnect device is able to provide tensile and compressive strength similar to the sucker rod string thereby eliminating at least one failure mode for the sucker rod string.
Abstract:
A method of running tubulars includes attaching a load collar to a first tubular; landing the load collar on a load support member; connecting a second tubular to the first tubular; removing the load collar from the first tubular; and lowering the first tubular and the second tubular. In one embodiment, at least one of the first tubular and the second tubular is a screen.
Abstract:
A pipe handler for assembling and deploying a string of threaded tubulars into a wellbore includes a pair of compensating bails and an elevator pivotally connected to the compensating bails. Each compensating bail includes: a first bail segment; a second bail segment; and a compensator connecting the respective first and second bail segments. Each compensator includes a load cylinder connected to the respective first bail segment and a linear actuator disposed in the respective load cylinder and operable to retract the respective second bail segment from a hoisting position to a ready position. Each second bail segment is engaged with the respective load cylinder in the hoisting position. The compensating bails are capable of supporting string weight in the hoisting position.
Abstract:
A method of drilling a subsea wellbore includes drilling the subsea wellbore and, while drilling the subsea wellbore: measuring a flow rate of the drilling fluid injected into a tubular string; measuring a flow rate of returns; comparing the returns flow rate to the drilling fluid flow rate to detect a kick by a formation being drilled; and exerting backpressure on the returns using a first variable choke valve. The method further includes, in response to detecting the kick: closing a blowout preventer of a subsea pressure control assembly (PCA) against the tubular string; and diverting the flow of returns from the PCA, through a choke line having a second variable choke valve, and through the first variable choke valve.
Abstract:
An expandable liner is used to re-complete a wellbore for a re-fracturing operation. The expandable liner may be used to cover the old perforations and provide a larger bore after expansion. The larger bore allows the new completion perforations and fracturing operation to be more easily achieved. In one embodiment, the expandable liner may have a rib disposed around an outer diameter of the expandable tubular, wherein the rib is configured to form a seal with the outer tubular.