Granted Patent B2

US 8,746,343 · App. 13/612,533 · Granted Jun 10, 2014

Inventors: Jim Fehr (Sherwood Park, CA); Daniel Jon Themig (Calgary, CA)

Assignee: Packers Plus Energy Services Inc.

Abstract

Claims (19)

1. A wellbore fluid treatment assembly comprising:

a tubing string including an inner bore and a tubular housing with a wall, an outer wall surface and an inner wall surface defining the inner bore through the tubular housing, the tubing string further including an uphole drift diameter uphole of the tubular housing;

a port through the wall of the tubular housing, the port providing access between the outer wall surface and the inner wall surface through the port;

a sliding sleeve installed in the tubular housing inner bore and slidable between (i) a closed-port position covering the port, wherein fluid cannot pass through the port, and (ii) a open-port position exposing the port to the inner bore and wherein fluid can pass through the port, the sliding sleeve including an outer diameter, an inner diameter defining an axial bore and a constriction along the inner diameter forming a seat; and

a plug moved by fluid pressure through the tubing string and sized to seal against the seat to drive the sliding sleeve from the closed-port position to the open-port position by fluid pressure;

wherein the seat is retrievable up through the tubular housing and axially moved up through the inner bore to remove the constriction from the tubing string.

2. The wellbore fluid treatment of claim 1 wherein after removing the constriction from the tubing string, the inner bore has a diameter substantially the same or greater than the uphole drift diameter.

3. The wellbore fluid treatment of claim 1 further comprising a plurality of tubular housings spaced apart in the tubing string and each of the tubular housings of the plurality of tubular housings includes a retrievable seat removable from the tubing string.

4. A method for treatment of a wellbore, the method comprising:

installing a tubing string in the wellbore, the tubing string including an inner bore and a tubular housing with a wall, an outer wall surface and an inner wall surface defining the inner bore through the tubular housing, the tubing string further including an uphole drift diameter uphole of the tubular housing; a port through the wall of the tubular housing, the port providing access between the outer wall surface and the inner wall surface through the port; and a sliding sleeve installed in the tubular housing inner bore in a closed-port position covering the port, wherein fluid cannot pass through the port, the sliding sleeve including an outer diameter, an inner diameter defining an axial bore and a constriction along the inner diameter forming a seat;

conveying a plug through the tubing string to land in the seat;

pumping fluid behind the plug to create a pressure differential across the sliding sleeve to drive the sliding sleeve to an open-port position exposing the port to the inner bore;

continuing to pump to introduce fluid through the port and into the wellbore accessed through the port;

pulling the seat axially up through the tubing string to remove the constriction from the tubing string inner bore; and

allowing produced fluids to flow through the port and up through the tubing string.

5. The method of claim 4 , wherein after pulling the seat, the method further comprises running in a tool past the port, the tool having a diameter greater than the constriction.

6. The method of claim 4 , wherein pulling the seat employs a retrieval tool.

7. The method of claim 4 , wherein after pulling the seat, the method further comprises installing a flow control sleeve over the port to return the port to a closed condition.

8. The method of claim 4 further comprising removing a second seat from the tubing string.

Assignments (1)

Continuity (8)