Tier 1 Energy Solutions Inc.

Other

Tier 1 Energy Tech, Inc.

Jeffrey Golinowski

Daniel P Lupien

Ronald Scott Alders

Trevor Rosten

Derek Kitchen

Nathan Kathol

Douglas Rosten

Sylvain Hotte

Cody Brown

Jeff King

Kevin O'Dwyer

A packer assembly includes (a) a mandrel bearing an expandable packer element, the mandrel having a ratchet section, a lower collet retaining shoulder, and defining a plurality of longitudinal slots; (b) a push sleeve connected to a ratchet ring by at least one shear pin, wherein the ratchet ring is disposed between push sleeve and the mandrel and engages the mandrel ratchet section; (c) a shift sleeve comprising an inner shift sleeve slidingly disposed within the mandrel and having a lower collet, the inner shift sleeve defining a profile for engaging a shifting tool, and an outer shift sleeve slidingly around the mandrel and connected to the inner shift sleeve with a plurality of bolts, wherein each bolt passes through a longitudinal slot defined by the mandrel; (d) wherein the shift sleeve and push sleeve is moveable between a running position and a released position. Also disclosed are methods of using a packer actuated by a sliding sleeve.

Coil shiftable packer

A method, related device and system for lifting a reservoir fluid in an oil and gas well involves allowing the reservoir fluid to flow in an axial uphole direction through an internal flow path of a production tubing disposed in the well. The internal flow path includes a Venturi profile configured to flash out a free gas phase from the reservoir fluid as the reservoir fluid flows in the axial uphole direction through the Venturi profile, such that the reservoir fluid comprises the free gas phase and a liquid phase. The internal flow path also includes a diffusion profile disposed above the Venturi profile and configured to condense the free gas phase into the liquid phase as the reservoir fluid flows in axial uphole direction through the diffusion profile.

Device and method for gas lift of a reservoir fluid

A swellable packer assembly includes a mandrel, a base pipe disposed within the mandrel, a swellable seal element retained externally on the mandrel, and a shearable member that releasably secures the base pipe to the mandrel. In use, the base pipe forms part of a downhole tubing string in a wellbore. The seal element is swelled with a swelling fluid to seal between an outer wall of the mandrel and a wellbore wall. The shearable member is allowed to shear so that the injection tubing string including the base pipe may move axially within to the wellbore, while the seal element and the mandrel remain stationary relative to wellbore, with the seal element in contact with the wellbore wall. The assembly may help to avoid distortion of and damage to the seal element that may otherwise occur due to thermal expansion and contraction of the downhole tubing string.

Swellable packer assembly for a wellbore system

A cable head for attaching a wireline to a downhole tool includes an upper tubular member and a lower tubular member removably attached by a threaded connection. The cable head includes a pack-off assembly disposed within the upper tubular member. The pack-off assembly includes a deformable pack-off element comprising an outer sidewall for sealing against an inner sidewall of the upper tubular member, and an inner sidewall for sealing around the wireline. The pack-off assembly includes a biasing means axially in line with the deformable pack-off element. The pack-off element and the biasing means are axially compressed between an internal shoulder of the upper tubular member and the lower tubular member when the upper and lower tubular members are removably attached by the threaded connection, to enhance the seal of the tubular pack-off element with the inner sidewall of the upper tubular member, and with the wireline.

Cable head for attaching a downhole tool to a wireline

A steam diverter apparatus for forming part of a downhole tubing string is provided. The apparatus may be used in a SAGD operation to control flow of steam into a formation. The apparatus includes a tubular housing defining steam-admitting ports, and containing a moveable shift sleeve. The apparatus is modifiable for use with position shifting tools of different outer diameters by interchanging first and second sets of the shift sleeve and insert rings having different minimum inner diameters within the housing. The open flow area of the apparatus is modifiable by plugs that block the ports and are removably attached to the housing. The plug, the shift sleeve, or both of them may be made of a dissolvable material, so that they can be dissolved by a chemical solution injected into the tubing string, for the purpose of controlling steam flow through the ports.

Steam diverter apparatus and method for controlling steam flow in a well

A flexible coupling for coupling sections of a downhole tubing string is provided. The flexible coupling has a central section with first and second ends, each end having a contact surface and a first part of a pivoting connector, the contact surface extending radially outward relative to the first part of the pivoting connector. The flexible coupling also has first and second coupling sections pivotally coupled to the first and second ends of the central section. Each of the first and second coupling sections have a tubing string attachment at a first end, a second part of the pivoting connector at a second end, and a contact surface at the second end, the contact surface extending radially outward relative to the second part of the pivoting connector. Pivotal movement of the first and second coupling sections relative to the central section is limited by engagement between the contact surfaces.

Flexible coupling for downhole drive string

A releasable connection for a downhole tool string is provided, having a first part with a connection profile and a second part with a releasable engagement profile that releasably engages the connection profile of the first part. The second part also has a locking piston, the locking piston moving axially along the second part between a locking position that locks the releasable engagement profile into engagement with the connection profile of the first part and a release position that permits the releasable engagement profile to release the connection profile of the second part, an expansion chamber in fluid communication with the locking piston, and a source of fluid pressure in communication with the expansion chamber, wherein, upon activation, the source of fluid pressure applies fluid pressure to move locking piston from the locking position toward the release position.

Releasable connection for a downhole tool string

A downhole packer includes a first locking member positioned at least partially around an outer surface of an oilfield tubular. The first locking member includes an inner surface that engages the outer surface of the oilfield tubular, and a tapered outer surface. A drive ring is positioned at least partially around the first locking member. The drive ring includes a reverse-tapered inner surface that engages the tapered outer surface of the first locking member. A first cap is movably coupled with the drive ring, disposed at least partially around the first locking member, and axially engaging the first locking member. Moving at least one of the first cap and the drive ring toward the other causes the drive ring to apply a radially-inward force on the first locking member, causing the first locking member to be secured to the tubular.

Growing community of inventors

Sherwood Park, Canada

Jeffrey Golinowski