Fluid loss well treatment

Patent metadata

Field	Value
Publication number	US-9677371-B2
Application number	US-201414417683-A
Country	US
Kind code	B2
Filing date	Jun 6, 2014
Priority date	Jun 6, 2013
Publication date	Jun 13, 2017
Grant date	Jun 13, 2017

Abstract

A well treatment for treating a well includes discrete stop loss elements to seal a fluid loss opening of a well. The discrete stop loss elements include polymer resistive to deformation with an initial stiffness in response to an initial strain rate of the polymer to produce a specified initial pressure signal and deformable with a subsequent, lower stiffness in response to a subsequent, lower strain rate of the polymer to produce a subsequent, different specified pressure signal.

First claim

What is claimed is:

1. A method, comprising:
initially plugging a fluid loss opening of a well with a plurality of discrete stop loss elements, the stop loss elements comprising a polymer, the polymer, while initially plugging the fluid loss opening, resisting deformation at an initial stiffness in response to an initial strain rate of the polymer to produce a specified initial pressure signal, the polymer comprising a viscoelastic polyurethane, a viscoelastic phenolic resin or a viscoelastic epoxy resin, wherein the polymer has:
a glass transition temperature in a range from about 78 to 156° C.,
a ratio of Moduli of Glassy to Rubbery State log ((E′ g )/(E′ r )) in a range from 0.5 to 2, wherein E′ g is a glassy modulus of the polymer and E′ r is a rubbery modulus of the polymer,
a loss modulus in a range from greater than about 80 MPa to 240 MPa for a tan □ peak equal to 0.2, and
a storage modulus in a range from greater than about 400 to 1200 MPa; and

continuing to plug the fluid loss opening with the plurality of discrete stop loss elements, the polymer, while continuing to plug the fluid loss opening, deforming at a subsequent, lower stiffness in response to a subsequent, lower strain rate to produce a subsequent, different specified pressure signal.

2. The method of claim 1 , further comprising sealing the fluid loss opening with a sealing material within the plurality of discrete stop loss elements.

3. The method of claim 1 , where the subsequent, lower strain rate is a substantially constant strain to allow the polymer to deform at the subsequent, lower stiffness.

4. The method of claim 1 , where initially plugging a fluid loss opening of a well with a plurality of discrete stop loss elements comprises clumping the plurality of stop loss elements together at the fluid loss opening.

5. The method of claim 1 , further comprising continuing to plug the fluid loss opening with the plurality of discrete stop loss elements, the polymer, while continuing to plug the fluid loss opening, resisting deformation at the initial stiffness in response to the initial strain rate of the polymer.

6. The method of claim 1 , where initially plugging a fluid loss opening of a well with a plurality of discrete stop loss elements comprises initially plugging a fluid loss opening of a well tool with a plurality of discrete stop loss elements.

7. The method of claim 6 , further comprising passing the plurality of discrete stop loss elements through the fluid loss opening to unplug the fluid loss opening, the polymer deforming at the subsequent, lower stiffness in response to a constant applied stress on the polymer.

8. The method of claim 1 , further comprising forming the polymer of the discrete stop loss elements by combining, in the well, materials comprising the discrete stop loss elements for in-well curing.

9. The method of claim 1 , further comprising flowing the plurality of discrete stop loss elements in a treatment fluid to the fluid loss opening, the treatment fluid comprising plugging material; and
while initially plugging the fluid loss opening with the plurality of discrete stop loss elements, allowing the plugging material of the treatment fluid to cure in the fluid loss opening to plug the fluid loss opening.

10. The method of claim 9 , where allowing the plugging material of the treatment fluid to cure in the fluid loss opening to plug the fluid loss opening comprises allowing cement to cure in the fluid loss opening to permanently plug the fluid loss opening.

11. A well treatment system for treating a well, the well treatment system comprising:
a plurality of discrete stop loss elements to seal a fluid loss opening of a well,
the discrete stop loss elements comprising polymer resistive to deformation with an initial stiffness in response to an initial strain rate of the polymer to produce a specified initial pressure signal and deformable with a subsequent, lower stiffness in response to a subsequent, lower strain rate of the polymer to produce a subsequent, different specified pressure signal;
wherein the polymer has:
a glass transition temperature in a range from about 78 to 156° C.,
a ratio of Moduli of Glassy to Rubbery State log ((E′ g )/(E′ r )) in a range from 0.5 to 2, wherein E′ g is a glassy modulus of the polymer and E′ r is a rubbery modulus of the polymer,
a loss modulus in a range from greater than about 80 MPa to 240 MPa for a tan □ peak equal to 0.2, and
a storage modulus in a range from greater than about 400 to 1200 MPa.

12. The well treatment system of claim 11 , where the fluid loss opening of the well is selected from the group consisting of a fluid loss opening in a well casing, a fluid loss opening in a wellbore wall of the well, and a fluid loss opening of a well tool.

13. The well treatment system of claim 11 , where the initial strain rate is a substantially oscillating strain rate and the subsequent, lower strain rate is a substantially constant strain rate.

14. The well treatment system of claim 11 , further comprising a pressure sensor of the well to assess pressure signals in the well.

15. The well treatment system of claim 11 , where the plurality of discrete stop loss elements includes a filler material within the stop loss elements.

16. The well treatment system of claim 15 , where the filler material is at least one of sand, proppant, fiber, cement, or chemical treatment.

Assignees

• Halliburton Energy Services Inc

Inventors

• Richards William Mark
• Chang Andy Cheng

Classifications

• E21B33/10 Primary

  in the borehole {(sealing the junction between main bore and laterals E21B41/0042)} · CPC title

• C09K8/487

  Fluid loss control additives; Additives for reducing or preventing circulation loss · CPC title

• E21B34/14

  operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools {(E21B34/066 takes precedence)} · CPC title

• E21B2033/105

  Fixed Constructions · mapped topic

• E21B33/1208 Primary

  characterised by the construction of the sealing or packing means (E21B33/1277 takes precedence) · CPC title