Tools and methods for use in completion of a wellbore

• US 10,227,845 B2
• Filed: 09/15/2015
• Issued: 03/12/2019
• Est. Priority Date: 10/18/2010
• Status: Active Grant

• Current Assignee: NCS Multistage Inc. (NCS Multistage Holdings, Inc.)
• Original Assignee: NCS Multistage Inc. (NCS Multistage Holdings, Inc.)
• Inventors: Getzlaf, Donald, Stromquist, Marty, Nipper, Robert, Willems, Timothy H.
• Primary Examiner(s): Coy, Nicole
• Application Number:
  US14/855,089
• Publication Number:
  US 20160010429A1
• Time in Patent Office: 1,274 Days
• CPC Class Codes: E21B 17/00 Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
• CPC Class Codes: E21B 17/1085 Wear protectors; Blast joints; Hard facing
• CPC Class Codes: E21B 17/20 Flexible or articulated drilling pipes , e.g. flexible or articulated rods, pipes or cables
• CPC Class Codes: E21B 2200/06 Sleeve valves
• CPC Class Codes: E21B 23/01 for anchoring the tools or the like E21B23/02 - E21B23/06 take precedence; anchoring of drives in the borehole E21B4/18
• CPC Class Codes: E21B 23/02 for locking the tools or the like in landing nipples or in recesses between adjacent sections of tubing E21B23/03 - E21B23/06 take precedence
• CPC Class Codes: E21B 33/12 Packers; Plugs used for cementing E21B33/134, E21B33/16
• CPC Class Codes: E21B 33/127 with inflatable sleeve E21B33/122, E21B33/124 take precedence
• CPC Class Codes: E21B 33/129 with mechanical slips for hooking into the casing E21B33/122, E21B33/124 take precedence
• CPC Class Codes: E21B 33/134 Bridging plugs
• CPC Class Codes: E21B 34/063 Valve or closure with destructible element, e.g. frangible disc E21B34/103 takes precedence
• CPC Class Codes: E21B 34/08 responsive to flow or pressure of the fluid obtained E21B34/10 takes precedence
• 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 34/14 operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools E21B34/066 takes precedence
• 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 43/114 Perforators using direct fluid action on the wall to be perforated, e.g. abrasive jets
• CPC Class Codes: E21B 43/12 Methods or apparatus for controlling the flow of the obtained fluid to or in wells E21B43/25 takes precedence; valve arrangements E21B34/00
• CPC Class Codes: E21B 43/14 Obtaining from a multiple-zone well
• CPC Class Codes: E21B 43/16 Enhanced recovery methods for obtaining hydrocarbons
• CPC Class Codes: E21B 43/25 : Methods for stimulating production by vibrating earth formations E21B43/003
• CPC Class Codes: E21B 43/26 : by forming crevices or fractures
• CPC Class Codes: E21B 43/267 : reinforcing fractures by propping
• CPC Class Codes: E21B 47/06 : Measuring temperature or pressure

Abstract

A ported tubular is provided for use in casing a wellbore, to permit selective access to the adjacent formation during completion operations. A system and method for completing a wellbore using the ported tubular are also provided. Ports within the wellbore casing may be opened, isolated, or otherwise accessed to deliver treatment to the formation through the ports, using a tool assembly deployed on tubing or wireline.

Claims

1. A method for shifting a sliding sleeve in a wellbore, comprising:

providing a wellbore lined with tubing having a nominal inner inside diameter, the tubing comprising a port closure sleeve slidably disposed within a tubular, the tubular having an inner profile for use in locating said sleeve;

providing a tool assembly comprising;

a locator engageable with said locatable inner profile of the tubular; and

a resettable anchor member;

deploying the tool assembly within the wellbore on coiled tubing;

engaging the inner profile with the locator;

setting the anchor within the wellbore to engage the sliding sleeve;

applying a downward force to the coiled tubing to slide the port closure sleeve with respect to the tubular,

wherein the port closure sleeve has no inner diameter that is less than the nominal inner diameter of the tubing.

2. The method as in claim 1, wherein the step of setting the anchor comprises application of a radially outward force with the anchor to the port closure sleeve so as to frictionally engage the sleeve with the anchor.

3. The method as in claim 1, wherein the port closure sleeve has an inner surface with an internal diameter that does not decrease at any point with axial distance from a midline of the sleeve and is free of any engagement profile.

4. The method as in claim 1, wherein the tool assembly further comprises a sealing member associated with the anchor, and wherein the method further comprises the step of setting the sealing member across the port closure sleeve to provide a hydraulic seal across the sleeve.

5. The method as in claim 1, wherein the step of applying the downward force comprises applying hydraulic pressure to the wellbore annulus.

6. A method for shifting a sliding sleeve in a wellbore, comprising:

providing a wellbore lined with tubing having a nominal inner diameter, the tubing comprising at least one port in a wall of the tubing and a sleeve slidably disposed within a tubular and moveable from a first, closed position wherein the sleeve covers the port to a second, open position wherein the sleeve is axially displaced from the port, the tubular having an inner profile for use in locating said sleeve;

providing a tool assembly comprising;

a locator engageable with said locatable inner profile of the tubular; and

a resettable sealing member;

deploying the tool assembly within the wellbore on coiled tubing;

engaging the inner profile with the locator;

setting the sealing member across the sliding sleeve;

applying a downward force on the sealing member to slide the sleeve together with the set sealing member with respect to the tubular; and

subsequently unsetting the sealing member from the sliding sleeve,

wherein the sleeve has no inner diameter that is less than the nominal inner diameter of the tubing.

7. The method as in claim 6, wherein the step of setting the sealing member comprises application of a radially outward force with the sealing member to the sleeve so as to frictionally engage the sleeve with the sealing member.

8. The method as in claim 6, wherein the sleeve comprises an inner surface of uniform diameter along its length, free of any profile.