A packer cup for use on downhole wellbore tools is provided herein. The packer cup has a composite annular body made from elastomer and/or polymer materials capable of accomplishing effective sealing at normal to high operating temperatures and at all pressure ranges in order to provide superior resistance to aggressive fluids, such as sour crude oil or gas, lubricating oil additives and amine corrosion inhibitors. The packer cup has a radial array of concave reinforcing wires that are retained by a metal cylindrical sleeve. In addition, the packer cup may include a support cup that is received about a lower tapered end in order to provide additional structural support to the cup.

A packer cup for use on downhole wellbore tools is provided herein. The packer cup has a composite annular body made from elastomer and/or polymer materials capable of accomplishing effective sealing at normal to high operating temperatures and at all pressure ranges in order to provide superior resistance to aggressive fluids, such as sour crude oil or gas, lubricating oil additives and amine corrosion inhibitors. The packer cup has a radial array of concave reinforcing wires that are retained by a metal cylindrical sleeve. In addition, the packer cup may include a support cup that is received about a lower tapered end in order to provide additional structural support to the cup.

Disclosed is a gravel pack service tool that utilizes an internal closure device to set a packer. One disclosed system includes a completion string including at least one packer, a service tool configured to be arranged within the completion string and having an interior that provides a flow path for fluids and a crossover tool, and a closure device arranged within the flow path and being actuatable between an open position and a closed position in response to a signature pressure pulse detected by the closure device, wherein, when the closure device is in the open position, the fluids are able to bypass the closure device and flow to lower portions of the service tool, and wherein, when the closure device is in the closed position, the fluids are prevented from bypassing the closure device and a pressure within the service tool is increased to set the at least one packer.

Disclosed is a gravel pack service tool that utilizes an internal closure device to set a packer. One disclosed system includes a completion string including at least one packer, a service tool configured to be arranged within the completion string and having an interior that provides a flow path for fluids and a crossover tool, and a closure device arranged within the flow path and being actuatable between an open position and a closed position in response to a signature pressure pulse detected by the closure device, wherein, when the closure device is in the open position, the fluids are able to bypass the closure device and flow to lower portions of the service tool, and wherein, when the closure device is in the closed position, the fluids are prevented from bypassing the closure device and a pressure within the service tool is increased to set the at least one packer.

A casing string is augmented with one or more variable flow resistance devices or “vibrating tools” to facilitate advancement of the casing and distribution of the cement in the annulus once the casing is properly positioned. Vibrating tools in the form of plugs can be pumped down and landed inside the casing string. The method includes vibrating the casing string while advancing the casing down the wellbore or while the cement is pumped into the annulus, or both. After the cementing operation is completed, the devices may be drilled out or retrieved with fishing tools to reopen the casing string for further operations. One or more wipers may be provided on the plugs, but the section housing the flow path may be free of wipers to allow the size and flow capacity of the flow path to be optimized.

A casing string is augmented with one or more variable flow resistance devices or “vibrating tools” to facilitate advancement of the casing and distribution of the cement in the annulus once the casing is properly positioned. Vibrating tools in the form of plugs can be pumped down and landed inside the casing string. The method includes vibrating the casing string while advancing the casing down the wellbore or while the cement is pumped into the annulus, or both. After the cementing operation is completed, the devices may be drilled out or retrieved with fishing tools to reopen the casing string for further operations. One or more wipers may be provided on the plugs, but the section housing the flow path may be free of wipers to allow the size and flow capacity of the flow path to be optimized.

A tubular joint installable on a tubular string disposable within a wellbore. The tubular joint may include includes a perforated section, a filter section, and a packer. The perforated section may be proximate a first end and may include a first plurality of orifices to allow fluid communication between a bore of the tubular joint and a first area surrounding the tubular joint proximate the perforated section. The filter section may be proximate a second end and may include a filter assembly sized to filter fluid flowing into the bore via a second plurality of orifices from a second area proximate the filter section. The packer may be disposed between the perforated section and the filter section and may be operable to isolate the first area from the second area when the tubular string is disposed within the well.

A wellbore tool includes a rod with a plurality of rod sections. The rod is configured to be placed within a wellbore casing of a low-pressure hydrocarbon well. A plurality of sealing elements are positioned at a downhole end of the rod. Each sealing element is configured to provide a gas-tight seal between the sealing element and an inner wall of the wellbore casing. A handle positioned at an uphole end of the rod provides a hand grip for a user of the wellbore tool.

A wellbore tool includes a rod with a plurality of rod sections. The rod is configured to be placed within a wellbore casing of a low-pressure hydrocarbon well. A plurality of sealing elements are positioned at a downhole end of the rod. Each sealing element is configured to provide a gas-tight seal between the sealing element and an inner wall of the wellbore casing. A handle positioned at an uphole end of the rod provides a hand grip for a user of the wellbore tool.

An isolation device for use with a casing gas separator. The device incorporates multiple cups, some upward-facing and others downward-facing. The downward-facing cup or cups seal against an internal surface of the casing gas separator to divert flow into the annulus of the separator and enable the separation process. The upward-facing cup or cups hold a pressurized fluid when the device is being located within the casing. Upon reaching the upper ports of the casing gas separator, the fluid releases into the annulus, allowing an operator to determine the location of the device and accurately place it within the casing gas separator.