Method and apparatus for wellbore fluid treatment

• US 8,397,820 B2
• Filed: 12/13/2010
• Issued: 03/19/2013
• Est. Priority Date: 11/19/2001
• Status: Expired due to Fees

• Current Assignee: Packers Plus Energy Services (USA), Inc.
• Original Assignee: Packers Plus Energy Services (USA), Inc.
• Inventors: Fehr, Jim, Themig, Daniel Jon
• Primary Examiner(s): Thompson, Kenneth L
• Application Number:
  US12/966,849
• Publication Number:
  US 20110278010A1
• Time in Patent Office: 827 Days
• Field of Search: 166/332.1, 166/334.4, 166/332.4, 166/318, 166/373, 166/386, 166/385
• US Class Current: 166/332.1
• CPC Class Codes: E21B 2200/06 Sleeve valves
• CPC Class Codes: E21B 33/1208 characterised by the construction of the sealing or packing means E21B33/1277 takes precedence
• CPC Class Codes: E21B 33/122 Multiple string packers
• CPC Class Codes: E21B 33/124 Units with longitudinally-spaced plugs for isolating the intermediate space
• CPC Class Codes: E21B 34/10 operated by control fluid supplied from outside the borehole
• CPC Class Codes: E21B 34/12 operated by movement of casings or tubings
• CPC Class Codes: E21B 34/142 unsupported or free-falling elements, e.g. balls, plugs, darts or pistons
• CPC Class Codes: E21B 43/00 Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells applicable only to water E03B
• CPC Class Codes: E21B 43/14 Obtaining from a multiple-zone well
• CPC Class Codes: E21B 43/164 Injecting CO2 or carbonated water in combination with organic material C09K8/594
• CPC Class Codes: E21B 43/25 Methods for stimulating production by vibrating earth formations E21B43/003
• CPC Class Codes: E21B 43/2605 using gas or liquefied gas
• CPC Class Codes: E21B 43/267 reinforcing fractures by propping
• CPC Class Codes: E21B 43/27 by use of eroding chemicals, e.g. acids

Abstract

A tubing string assembly is disclosed for fluid treatment of a wellbore. The tubing string can be used for staged wellbore fluid treatment where a selected segment of the wellbore is treated, while other segments are sealed off. The tubing string can also be used where a ported tubing string is required to be run in a pressure tight condition and later is needed to be in an open-port condition.

Claims

1. The 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) an open-port position exposing the port to the inner bore and 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; and

further comprising an inwardly protruding shoulder in the inner bore downhole of the sliding sleeve against which the sliding sleeve is abutter in the open-port position;

wherein the sliding sleeve is retrievable, with the outer diameter sized less than the uphole drift diameter such that the sliding sleeve can be removed from the tubular housing and axially moved up though the inner bore.

2. The wellbore fluid treatment assembly of claim 1, wherein the sliding sleeve further comprises a recess for engagement by a retrieval tool.

3. The wellbore fluid treatment assembly of claim 1, further comprising an installation site for the sliding sleeve, the installation site being empty when the sliding sleeve is axially moved up through the inner bore and a flow control sleeve installable in the empty installation site to reclose the port.

4. The wellbore fluid treatment assembly as in claim 3, wherein the flow control sleeve includes a lock component for locking into a portion of the installation site.

5. The wellbore fluid treatment assembly as in claim 4, wherein the lock component is a plurality of outwardly extending collet fingers and the portion is a groove in the installation site.

6. 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 sliding sleeve axially up through the tubing string to remove the sliding sleeve from the tubing string; and

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

7. The method of claim 6, wherein after pulling the sliding sleeve, the method further comprises running in a tool past the port with a diameter greater than the constriction.

8. The method of claim 6, wherein pumping fluid includes driving the sliding sleeve against a stop shoulder when the sliding sleeve assumes the port-open position.

9. The method of claim 6, wherein pulling the sliding sleeve includes engaging the sliding sleeve with a retrieval tool on a wireline.

10. The method of claim 6, wherein after pulling the sliding sleeve, the method further comprises installing a flow control sleeve over the port to return the port to a closed condition.

11. The method as in claim 10, wherein installing the flow control sleeve includes engaging collet fingers of the sleeve into a groove in the inner wall surface of the tubular housing.

12. The method of claim 6, wherein after pulling the sliding sleeve, the method further comprises pulling a second sliding sleeve from downhole of the tubular housing axially up through the tubular housing to remove the second sliding sleeve from the tubing string.

13. 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 an installation site 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) an 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 wherein the sliding sleeve is retrievable, with the outer diameter sized less than the uphole drift diameter such that the sliding sleeve can be removed from the tubular housing and axially moved up through the inner bore, the installation site being empty when the sliding sleeve is axially moved up through the inner bore; and

a flow control sleeve installable in the installation site, when empty, to reclose the port.

14. The wellbore fluid treatment assembly as in claim 13, wherein the flow control sleeve includes a lock component for locking into a portion of the installation site.

15. The wellbore fluid treatment assembly as in claim 14, wherein the lock component is a plurality of outwardly extending collet fingers and the portion is a groove in the installation site.