Halliburton Energy Services, Inc.

Daniel Keith Moeller

Brock Wayne Watson

Donald R Smith

Matthew Ryan Gray

Nicholas Lee Strohla

Kevin J Miller

Xiaoguang Allan Zhong

Shobeir Pirayeh Gar

Shawn Ray Webb

Michael Linley Fripp

David Jon Tilley

Michael Rick Johnson

Sean Christopher Canning

Adam J Milne

Joseph Ray Collins

James Todd Johnson

Phillip Michael Morgan

Sean Canning

Donald Ray Smith

Provided herein are embodiments of a frac plug for use downhole in a wellbore, a system, and a method for creating a pressure differential in the wellbore or performing an operation downhole in the wellbore. In one embodiment a plug for use within a wellbore comprises a mandrel; and a flow restrictor positioned within an inner diameter of the mandrel. In one embodiment, a method may include positioning a frac plug at a depth inside a casing of a wellbore formed in a subsurface formation, wherein one or more components are coupled with the frac plug, the frac plug comprising: a mandrel; and a flow restrictor positioned within the mandrel; setting the frac plug to contact an inner wall of the casing; and creating a pressure differential within the wellbore with the flow restrictor of the plug.

Use of turbulent flow in a frac plug

An apparatus comprising a singular tubular structure to be positioned inside casing of a wellbore formed in a subsurface formation, wherein the singular tubular structure is configured to expand to contact an inner wall of the casing and provide differential pressure integrity in the wellbore while an isolating component is positioned in the singular tubular structure.

Expandable tubular structure for maintaining differential pressure integrity in a wellbore

Exemplary toe sleeve embodiments, for example for hydrocarbon wellbore casing, can have a closure mechanism with at least two different operations for opening. For example, the closure mechanism may include a degradable element and a non-degradable element. The degradable element may be configured to maintain closure of the toe sleeve during pressure testing, while the non-degradable element may be rated to open at a lower pressure once the degradable element has degraded. This approach may allow effective pressure testing of the casing, while ensuring that the toe sleeve can be opened effectively without risk of damage to the casing.

Toe sleeves and methods of use

A frac plug defines a central passage therethrough and is movable from an unset to a set position in a well casing. A single slip ring assembly is supported by the bottom shoe and a slip wedge is positioned in slidable relationship to the single slip ring assembly. A sealing element is supported by the slip wedge. A deformable ball seat is movable axially relative to the sealing element and the sealing element is expandable radially outwardly to engage and seal against the well casing upon the application of a force applied thereto by the deformable ball seat.

Single slip frac tool

A frac plug has a bottom shoe, a single slip ring supported by the bottom shoe, a slip wedge positioned above the slip ring and axially movable relative to the slip wedge, a radially outwardly expandable sealing element supported by the slip wedge and a deformable backup shoe fixed to the sealing element. The deformable backup shoe has a cap covering at least a portion of a top surface of the sealing element and an outer leg extending along at least a portion of an outer surface of the sealing element. A ball seat is insertable into the radially outwardly expandable sealing element.

A fluid signal generator configured to produce fluid pulses in a fluid column of a wellbore are described. The fluid pulses represent data and/or other information to be transmitted from a downhole device, such as a fluid plug apparatus located within the borehole of the wellbore, to one or more other devices located away from the downhole device, including devices located above a surface of the wellbore. The fluid plug may be configured to provide a fluid seal between a first portion of the wellbore and a second portion of the wellbore prior to and during a fluid treatment procedure being performed on the wellbore.

Downhole telemetry during fluid injection operations

A downhole tool subassembly having an outer sleeve with a first set of apertures extending from an inner bore through an external surface of the outer sleeve. The downhole tool subassembly further includes a pin coupled to the outer sleeve and extending inward from the inner bore of the outer sleeve, and an inner sleeve slidingly engaged with the with outer sleeve. The inner sleeve has a slot and a second set of apertures extending from a sleeve bore of the inner sleeve through an external surface of the inner sleeve, and is operable to restrict flow across the first set of apertures when the inner sleeve is in a first position. The pin engages the slot, which includes a first tracking path and a second tracking path. The slot also includes a first transition path extending from the first tracking path to the second tracking path.

Top-down squeeze system and method

A diverter assembly includes a tubing segment and one or more sleeve members disposed therein. The tubing segment includes apertures that are selectively alignable with apertures of an inner sleeve disposed within the tubing segment. The tubing segment includes a series of stops (e.g., shear pins) to arrest movement of the first sleeve within the bore of the tubing segment. A first one or more ball seats are included in the first sleeve such that deployment of a first ball and pressurization of the well above the first ball causes a first set of shear pins to fail, thereby allowing the first sleeve to slide downhole to cause apertures of the sleeve to align with apertures of the tubing segment, thereby causing fluid to flow to an annulus between the tubing segment and wellbore wall.

A downhole tool subassembly has an outer sleeve with a first set of apertures extending from an inner bore of the outer sleeve. An intermediate sleeve positioned is within the outer sleeve and defines an intermediate flow path extending from an inner bore of the intermediate sleeve to a cavity formed between the uphole portion of the outer sleeve and the downhole portion of the intermediate sleeve. An inner sleeve is positioned within the intermediate sleeve and has an external sealing portion that restricts flow across the intermediate flow path when the downhole tool is in a first configuration.

A method of forming an entry guide at an end of a tubular string in a wellbore can include conveying a forming device into the wellbore, and deforming the end of the tubular string from a cylindrical shape to an outwardly widening shape with the forming device. A method of forming an entry guide at an end of an expanded liner hanger in a wellbore can include outwardly expanding the liner hanger, thereby sealingly securing a tubular string in the wellbore, and deforming the end of the liner hanger from a cylindrical shape to an outwardly widening shape with a forming device.

Entry guide formation on a well liner hanger

An improved liner hanger system is disclosed. The improved liner hanger system comprises a liner hanger positioned within a casing. The liner hanger comprises a spiked portion having one or more spikes, wherein the spikes comprise a flat portion. At least one of the one or more spikes is expandable and the flat portion of each of the one or more spikes interfaces with the casing when the spike is in the expanded position. A liner is coupled to the liner hanger.

Liner hanger system

A downhole oilfield tool assembly comprises a mandrel, a ball valve oriented to block downwards flow through the mandrel in a closed position, a first piston located above the ball valve and at least partly around an outside of the mandrel. The first piston is configured to develop motive force from a pressure differential between an interior of the mandrel and an exterior of the downhole oilfield tool assembly.

Low equivalent circulation density setting tool

A downhole tool for use in a well. A pumpable plug is used to urge bottom hole assemblies to a desired location in a well. The pumpable plug has a diameter greater than the maximum outer diameter of the casing in which the bottom hole assembly is to be located.

Downhole tool with pumpable section

A downhole tool for use in a well. The tool has a packer assembly and a pumpable plug associated with the packer assembly. The pumpable plug has a diameter greater than the maximum outer diameter of the packer assembly. The pumpable plug may be pumped through a casing having a diameter larger than that for which the packer assembly is designed and will urge the packer assembly through the large diameter casing into a smaller diameter casing for which the packer assembly is designed.

A downhole oilfield tool assembly is provided. The tool assembly comprises a mandrel, a valve oriented to block downwards flow through the mandrel in a closed position, a first piston located above the valve and at least partly around an outside of the mandrel. The first piston is configured to develop motive force from a pressure differential between an interior of the mandrel and an exterior of the downhole oilfield tool assembly.

Growing community of inventors

Celina, TX, United States of America

Daniel Keith Moeller