Method and system for treating a subterranean formation using diversion

• US 7,934,556 B2
• Filed: 05/21/2007
• Issued: 05/03/2011
• Est. Priority Date: 06/28/2006
• Status: Active Grant

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Fredd, Christopher N., Lassek, John, Bentley, Doug, Miller, Charles, Clark, William Ernest, Daniels, John
• Primary Examiner(s): Neuder; William P
• Application Number:
  US11/751,172
• Publication Number:
  US 20080000639A1
• Time in Patent Office: 1,443 Days
• Field of Search: 166/281, 166/250.01, 166/250.17
• US Class Current: 166/281
• 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 43/25 Methods for stimulating production by vibrating earth formations E21B43/003

Abstract

A method well treatment includes establishing fluid connectivity between a wellbore and at least one target zone for treatment within a subterranean formation, which is intersected by a wellbore. The method includes deploying coiled tubing into the wellbore and introducing a treatment composition into the wellbore. The method includes contacting a target zone within the subterranean formation with the treatment composition, introducing a diversion agent through the coiled tubing to an interval within a wellbore and repeating the introduction of the treatment, the contacting of the target zone and the introduction of the diversion agent for more than one target zone.

Claims

1. A method, comprising:

establishing fluid connectivity between a wellbore and a first target zone, and between the wellbore and a second target zone, wherein the first target zone and second target zone comprise zones for treatment within a subterranean formation intersected by a wellbore, wherein the second target zone is above the first target zone;

positioning a coiled tubing into the wellbore;

performing a first treatment step on the first target zone, wherein the first treatment step comprises contacting a treated zone with a treatment fluid;

performing a second treatment step on the first target zone, wherein the second treatment step comprises introducing a diversion agent comprising a degradable material to the treated zone;

performing the first treatment step on the second target zone;

degrading the diversion agent after the performing the first treatment step on the second target zone; and

measuring a wellbore parameter wherein measuring comprises measuring microseismic activity.

8. The method of claim 1, further comprising establishing fluid connectivity with at least one additional target zone, the method further comprising performing the second treatment step on the second target zone, and successively treating each additional target zone except a final target zone by performing the first treatment step and the second treatment step on each additional target zone, and treating the final target zone by performing the first treatment step on the final target zone.

9. The method of claim 8, wherein establishing fluid connectivity with at least one additional target zone comprises performing a perforation operation on the at least one additional target zone after performing the treatment step on the first target zone and before removing the coiled tubing from the wellbore.

10. The method of claim 8, wherein the first target zone, second target zone, and additional target zones are treated in an order from a lowest in-situ stress to a highest in-situ stress.

11. The method of claim 8, wherein the first target zone, second target zone, and additional target zones are treated in an order from a top zone to a bottom zone.

2. The method of 1, wherein the wellbore is cased, the method further comprising perforating the casing.

3. The method of 1, wherein the treatment composition comprises a stimulation fluid.

4. The method of claim 3, wherein the act of introducing the treatment composition comprises pumping the composition under pressure.

5. The method of 1, wherein at least a portion of the wellbore comprises a generally horizontal section.

6. The method of 1, wherein the diversion agent comprises fiber.

7. The method of 1, wherein a portion of the wellbore is deviated or horizontal.

12. A method, comprising:

establishing fluid connectivity between a wellbore and a first target zone, and between the wellbore and a second target zone, wherein the first target zone and second target zone comprise zones for treatment within a subterranean formation intersected by a wellbore, wherein the second target zone is above the first target zone;

positioning a coiled tubing into the wellbore;

performing a first treatment step on the first target zone, wherein the first treatment step comprises contacting a treated zone with a treatment fluid;

performing a second treatment step on the first target zone, wherein the second treatment step comprises introducing a diversion agent comprising a degradable material to the treated zone and wherein the diversion agent is stored in the coiled tubing between acts of introducing the diversion agent to an interval;

performing the first treatment step on the second target zone;

degrading the diversion agent after the performing the first treatment step on the second target zone; and

measuring a wellbore parameter wherein measuring comprises measuring microseismic activity.

13. A method, comprising:

establishing fluid connectivity between a wellbore and a first target zone, and between the wellbore and a second target zone, wherein the first target zone and second target zone comprise zones for treatment within a subterranean formation intersected by a wellbore, wherein the second target zone is above the first target zone;

positioning a coiled tubing into the wellbore;

performing a first treatment step on the first target zone, wherein the first treatment step comprises contacting a treated zone with a treatment fluid;

performing a second treatment step on the first target zone, wherein the second treatment step comprises introducing a diversion agent comprising a degradable material to the treated zone;

performing the first treatment step on the second target zone;

degrading the diversion agent after the performing the first treatment step on the second target zone; and

measuring a wellbore parameter wherein measuring comprises measuring microseismic activity and measuring a parameter indicative of diversion.