Comitt Well Solutions US Holding Inc.

Comitt Well Solutions LLC

Other

Comitt Well Solutions US Holdings Inc.

Peter Kris Cleven

Roger Antonsen

Mohamed Ibrahim Saraya

A resettable pressure activated device, comprises an inner wall, a return spring, a resilient element and an axially movable piston arranged around the inner wall. The piston comprises a radially extending piston area in fluid communication with a central bore within the inner wall such that the piston moves in an activation direction when a bore pressure within the central bore exceeds the pressure around the device by a predetermined release pressure.

Resettable pressure activated device

A system () for stimulating a well with an annulus () formed by a string () and a wellbore (), wherein the system () comprises a pressure activated injection assembly () configured to open at an activation pressure below an injection pressure and a mechanically operated sand control assembly () configured to flush the annulus () after injection. The system () comprises a pressure activated flushing device () mounted uphole from the injection assembly () and configured to open radial flush ports () between the interior of string () and the annulus () at a flushing pressure above the injection pressure. An optional release mechanism for the pressure activated injection assembly () is also disclosed.

System for stimulating a well

A system for stimulating a well with an annulus formed by a string and a wellbore. The system includes an injection assembly with at least two zone isolation packers configured to set upstream and downstream of a target zone at pressures above a predetermined activation pressure, and unset at pressures below the activation pressure.

System and method for stimulating a well

A system () for positioning a working tool () in a wellbore (). The positioning system () comprises a casing element () with a marker () provided on an inner surface, the marker () having a distinct diameter different from the inner diameter of the casing element (). The system further comprises a positioning tool () with a latching element () adapted to form a latch () with the marker (), and a force detector () adapted to detect an axial latching force (F) applied to a tubing string () from the latch () when the casing element () is located within the wellbore () and the force detector () is located at a surface () outside the wellbore ().

Positioning system

A check valve for an injection string, comprises a cylindrical house with a central bore. A piston has a piston area exposed to the central bore, a protective sleeve at one end and a contact point affixed to the piston. A return spring is arranged between the house and the contact point so as to oppose a pressure force exerted on the piston area. A flapper valve&#x2014;comprises a blade rotatable about a hinge between a closed position where the blade blocks a reverse flow through the central bore and an open position where the blade is received in a recess in a wall of the central bore. The piston is axially movable within the house between a first position where the protective sleeve is displaced from the recess and a second position where the protective sleeve covers the recess.

Check valve

A complementary valve () for a movable string () in a wellbore application, wherein the movable string () comprises: a flow activated valve () configured to open when a flow through a central bore () is less than a predetermined threshold and to close if the flow exceeds the threshold, and a pressure activated device () configured to be activated when an activation pressure, defined as the difference between a bore pressure within the central bore () and an ambient pressure around the string (), is greater than or equal to a first activation pressure and to be deactivated when the activation pressure is less than the first activation pressure. The complementary valve () is configured to open a fluid connection () between the central bore and the ambient wellbore if the activation pressure is less than the first activation pressure, and to close the fluid connection when the activation pressure is equal to or greater than the first activation pressure. Thereby, the complementary valve () ensures that the pressure activated device () is reset after use.

Methods and systems for a complementary valve

A casing having an inner diameter and an outer diameter, a packer positioned on a tool configured to expand across an annulus, and a pressure port positioned within a between the inner diameter and the outer diameter of the casing. The pressure port includes a first end being positioned on a lower annulus on a first side of the packer and second end being positioned on an upper annulus on a second side of the packer, wherein the pressure port is configured to create a pressure differential between the upper annulus and the lower annulus.

Methods and systems for setting and unsetting packers within a well

A resettable pressure activated device (), comprises an inner wall (), a return spring (), a resilient element () and an axially movable piston () arranged around the inner wall (). The piston () comprises a radially extending piston area () in fluid communication with a central bore () within the inner wall () such that the piston () moves in an activation direction when a bore pressure within the central bore () exceeds the pressure around the device by a predetermined release pressure. The return spring () is configured to provide a return force that is directed opposite the activation direction and has a magnitude sufficient to return the piston () to an idle position when the bore pressure drops below a predetermined reset level. The resilient element () provides a retaining force, e.g. a friction force, equal to the difference between the release force and the return force. In a preferred embodiment, the retaining force is adjustable by adjustment means ().

An apparatus to inject a fluid into a geological formation. The apparatus includes a central bore running axially through the apparatus; a normally-closed sleeve valve with a sliding sleeve, the sleeve valve configured to open at a sleeve activation pressure; an upstream packer disposed upstream from the sleeve valve; a downstream packer disposed downstream from the sleeve valve; and a normally-open bottom valve disposed downstream from the downstream packer, the bottom valve configured to block axial fluid flow at a first bore pressure. The upstream packer and the downstream packer are configured to set at a second bore pressure between the first bore pressure and the sleeve activation pressure.

Apparatus for injecting a fluid into a geological formation

The present application describes a velocity chamber to regulate a velocity of fluid between an outer diameter of a piston, and an insert to limit, reduce, etc. erosion against the tool and casing.

Methods and systems for a tool with a chamber to regulate a velocity of fluid between an outer diameter of a piston and an insert

The present application describes methods and systems for a tool with a new check valve. The check valve may include a piston sleeve that is configured to move towards the proximal end of the tool to seal restrictive ports in a center of the tool responsive to creating a force on the piston sleeve. In embodiments, the movement of the piston sleeve may be counter to the flow of fluid through an inner diameter of the tool, such that the tool may be resettable and repeatable based on fluid flow and/or pressure differentials and not based on drag force through an inner diameter of the tool.

Methods and systems for a pressure controlled piston sleeve

Examples of the present disclosure relate to systems and methods for fracturing systems that maintain a substantially constant pressure differential between a first pressure zone and a second pressure zone.

Methods and systems for maintaining a pressure differential between pairs of packers

Embodiments disclosed herein describe fracturing methods and systems, wherein pressure differentials and fluid flow rates may be utilized to stimulate multiple zones, sleeves, or ports with the same tool.

Methods and systems for stimulating and restimulating a well

A system for stimulating a well with an annulus formed by a string and a wellbore, wherein the system includes an injection assembly, a normally closed injection valve, a normally open flow activated bottom valve, a sand control element, a mechanically operated sand control valve, a releasable anchor configured to be set in the wellbore downstream from the sand control valve.

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Grand-Barachois, Canada

Peter Kris Cleven