Methods for manipulation of the flow of fluids in subterranean formations

• US 7,987,910 B2
• Filed: 11/07/2007
• Issued: 08/02/2011
• Est. Priority Date: 11/07/2007
• Status: Expired due to Fees

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Hutchins, Richard D., Kubala, Gregory, Hinkel, Jerald J.
• Primary Examiner(s): Bates; Zakiya W.
• Application Number:
  US11/936,362
• Publication Number:
  US 20090118143A1
• Time in Patent Office: 1,364 Days
• Field of Search: None
• US Class Current: 166/279
• CPC Class Codes: C09K 8/602 containing surfactants
• CPC Class Codes: C09K 8/82 Oil-based compositions C09K8/64 takes precedence
• CPC Class Codes: E21B 43/32 Preventing gas- or water-coning phenomena, i.e. the formation of a conical column of gas or water around wells

Abstract

A method of treating a subterranean formation penetrated by a wellbore to mitigate the production of unwanted fluids from the wellbore is carried out by forming a treatment fluid containing at least one of an oil-wetting or water-repelling surfactant and a carrier fluid. The treatment fluid is then introduced into the wellbore. The treatment or treatments may be performed remedially or prophylacticaly. The treatment may include the completion and production of zones containing the undesirable fluid(s) and the deliberate formation of cones therein.

Claims

1. A method of treating a subterranean formation penetrated by a wellbore to mitigate the production of undesirable fluid from the wellbore, the method comprising:

producing the undesirable fluid from a zone predominantly containing the undesirable fluid so as to form a cone from a zone predominantly containing desirable fluid into the zone predominantly containing the undesirable fluid;

forming a treatment fluid comprising a carrier fluids and at least one of an oil-wetting or water-repelling surfactant;

introducing the treatment fluid into the wellbore; and

,

subsequently producing from the zone predominantly containing the desirable fluid.

2. The method of claim 1, wherein the treatment fluid is introduced into the zone predominantly containing the desirable fluid prior to producing the undesirable fluid from the zone predominantly containing the undesirable fluid so as to form a cone from the zone predominantly containing the desirable fluid into the zone predominantly containing the undesirable fluid.

3. The method of claim 1, wherein the treatment fluid is introduced into the zone predominantly containing the undesirable fluid prior to producing the undesirable fluid from the zone predominantly containing the undesirable fluid so as to form a cone from the zone predominantly containing the desirable fluid into the zone predominantly containing the undesirable fluid.

4. The method of claim 1, wherein the carrier fluid is selected from a gas, crude oil, mineral oil, non-aqueous fluids in which the oil-wetting or water-repelling surfactants are soluble, non-aqueous fluids that do not substantially alter surface wettability from generally neutral to oil wet, and non-aqueous fluids in which the oil-wetting or water-repelling surfactants are dispersible.

5. The method of claim 1, wherein an overflush of at least one of an aqueous fluid or non-aqueous fluid containing substantially no oil-wetting or water-repelling surfactant is introduced into the formation following introduction of the treatment fluid.

6. The method of claim 1, further comprising introducing a blocking agent into the wellbore following introduction of the treating fluid.

7. The method of claim 1, wherein the carrier fluid is aqueous.

8. The method of claim 1, wherein the carrier fluid is non-aqueous and the desirable fluid consists of crude oil.

9. The method of claim 1, wherein the surfactant concentration is less than the solubility limit within the carrier fluid at the temperature of use.

10. The method of claim 1, wherein the surfactant provides a reduction in capillary pressure or changes the contact angle to a value of from about 70 to about 110 degrees.

11. The method of claim 1, wherein the treatment fluid is an aqueous fluid and the surfactant is present in the treatment fluid.

12. The method of claim 11, wherein the surfactant is present in the treatment fluid in an amount of from about 1 to about 50 times above the critical micelle concentration (CMC) of the surfactant for the aqueous fluid.

13. The method of claim 1, wherein the well is shut in for a period sufficient to accomplish the required alteration of the formation treated.

14. The method of claim 1, further comprising introducing an acidizing fluid into the formation through the wellbore and removing at least a portion of the acidizing treatment fluid through the wellbore after a preselected period of time prior to introducing the treatment fluid into the wellbore.

15. The method of claim 1 wherein following the introduction of the treatment fluid, the well is shut-in for a time from about 12 hours to about 2 weeks prior to producing the wellbore.

16. The method of claim 1, wherein the treatment fluid is introduced into the wellbore as a prepad prior to introduction of pad fluid in a hydraulic fracturing treatment.

17. The method of claim 1, further comprising subsequent to introduction of the treatment fluid, monitoring fluids produced from the wellbore for surfactant content and retreating the well with a second treatment fluid when the surfactant content of the produced fluids reaches a preselected level.

18. A method of treating a subterranean formation penetrated by a wellbore to mitigate the production of undesirable fluid(s) from the wellbore, where a cone of the undesirable fluid exists in the zone predominantly containing the desirable fluid, the method comprising:

forming a treatment fluid comprising a carrier fluid and at least one of an oil-wetting or water-repelling surfactant;

introducing the treatment fluid into the wellbore; and

,

and subsequently producing the well.

19. The method of claim 18 wherein a preflush of at least one of an aqueous fluid or non-aqueous fluid containing substantially no oil-wetting or water-repelling surfactant is introduced into the formation prior to introduction of the treatment fluid.

20. The method of claim 18 wherein an overflush of at least one of an aqueous fluid or non-aqueous fluid containing substantially no oil-wetting or water-repelling surfactant is introduced into the formation following introduction of the treatment fluid, and wherein following the introduction of the treatment fluid, the well is shut-in for a time from about 12 hours to about 2 weeks prior to producing the wellbore.

21. The method of claim 18, further comprising subsequent to introduction of the treatment fluid, monitoring fluids produced from the wellbore for surfactant content and retreating the well with a second treatment fluid when the surfactant content of the produced fluids reaches a preselected level.