Control of fine particulate flowback in subterranean wells

• US 5,775,425 A
• Filed: 05/19/1997
• Issued: 07/07/1998
• Est. Priority Date: 03/29/1995
• Status: Expired due to Term

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Nguyen, Philip D., Bowles, Bobby K., Parker, Mark A., Weaver, Jim D., Stanford, James R., Dewprashad, Brahmadeo, Wilson, Steven F.
• Primary Examiner(s): Suchfield, George A.
• Application Number:
  US08/858,312
• Time in Patent Office: 414 Days
• Field of Search: 166/276, 166/280, 166/281, 166/295, 507/924, 523/131
• US Class Current: 166/276
• CPC Class Codes: C09K 8/5086 obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds
• CPC Class Codes: C09K 8/54 Compositions for in situ inhibition of corrosion in boreholes or wells
• CPC Class Codes: C09K 8/56 Compositions for consolidating loose sand or the like around wells without excessively decreasing the permeability thereof compositions for plastering borehole walls C09K8/50; Soil-conditioning materials or soil-stabilising materials in general C09K17/00
• CPC Class Codes: C09K 8/5755 obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds
• CPC Class Codes: C09K 8/62 Compositions for forming crevices or fractures
• CPC Class Codes: C09K 8/80 Compositions for reinforcing fractures, e.g. compositions of proppants used to keep the fractures open
• CPC Class Codes: C09K 8/805 Coated proppants
• CPC Class Codes: C09K 8/88 macromolecular compounds
• CPC Class Codes: C23F 11/143 Salts of amines
• CPC Class Codes: C23F 11/145 Amides; N-substituted amides
• CPC Class Codes: C23F 11/173 Macromolecular compounds
• CPC Class Codes: E21B 41/02 in situ inhibition of corrosion in boreholes or wells
• CPC Class Codes: E21B 43/025 Consolidation of loose sand or the like round the wells without excessively decreasing the permeability thereof
• CPC Class Codes: E21B 43/04 Gravelling of wells
• CPC Class Codes: E21B 43/267 reinforcing fractures by propping
• CPC Class Codes: Y10S 166/902 for inhibiting corrosion or coating
• CPC Class Codes: Y10S 507/924 with specified propping feature

Abstract

The present invention provides a method of treating a wellbore penetrating a subterranean formation with a treatment fluid whereby fine particulate flowback is reduced or prevented. The method includes the steps of providing a fluid suspension including a mixture of a particulate coated with a tackifying compound, pumping the suspension into a subterranean formation and depositing the mixture within the formation whereby the tackifying compound retards movement of at least a portion of any fine particulate within the formation upon flow of fluids from the subterranean formation through the wellbore. Alternatively, the tackifying compound may be introduced into a subterranean formation in a diluent containing solution to deposit upon previously introduced particulates to retard movement of such particulates and any fines subject to flow with production of fluids from the subterranean formation.

Claims

1. A method of treating a subterranean formation to control fines migration comprising the steps of:

introducing a particulate-containing fluid suspension into a subterranean formation subject to fines migration through a wellbore;

admixing with at least a portion of said particulate in said fluid suspension an effective amount of a liquid or solution of a tackifying compound whereby at least a portion of said particulate is at least partially coated by said compound such that the continuous critical resuspension velocity of said at least partially coated particulate is increased by in excess of about 30 percent when tested at a level of 0.5% active material by weight over said particulate alone with water;

depositing the tackifying compound coated particulate in the subterranean formation; and

flowing back fluid from the formation whereby the tackifying compound coated particulate retards movement of at least a portion of any fines moving with said flowback fluid by adhering said fines to said coated particulate.

2. The method of claim 1 wherein said tackifying compound comprises predominately a condensation reaction product of a dimer acid containing some trimer and higher oligomers and some monomer acids with a polyamine.

3. The method of claim 2 wherein said polyamine comprises at least one member selected from the group of ethylenediamine, diethylenetriamine, triethylenetetraamine, tetraethylene pentaamine and aminoethylpiperazine.

4. The method of claim 1 wherein said tackifying compound comprises a liquid or solution of a polyamide.

5. A method of treating a subterranean formation to control fines migration comprising the steps of:

introducing a treatment fluid into a subterranean formation through a wellbore at a rate and pressure sufficient to create at least one fracture in said formation;

admixing with at least a portion of said fluid, a particulate which is introduced into and subsequently deposited within said fracture;

admixing with at least a portion of said particulate an effective amount of a liquid or solution of a tackifying compound whereby at least a portion of said particulate is at least partially coated by said compound such that the continuous critical resuspension velocity of said at least partially coated particulate is increased by in excess of about 30 percent when tested at a level of 0.5% active material by weight over said particulate alone with water;

depositing the tackifying compound coated particulate in the subterranean formation; and

flowing back fluid from the formation whereby the tackifying compound coated particulate retards movement of at least a portion of any fine particulate flowing back to said wellbore within said formation by adhering said fines to said coated particulate.

6. The method of claim 5 wherein said tackifying compound is admixed with said particulate in an amount of from about 0.05 to about 3.0 percent by weight of said particulate.

7. The method of claim 5 wherein said tackifying compound is admixed with said particulate in an amount of from about 0.1 to about 2 percent by weight of said particulate.

8. The method of claim 5 wherein said coated particulate has a continuous critical resuspension velocity in excess of 50 percent over said particulate alone.

9. The method of claim 5 wherein said tackifying compound comprises a liquid or solution of a polyamide.

10. The method of claim 5 wherein said tackifying compound comprises predominately a condensation reaction product of a dimer acid containing some trimer and higher oligomers and some monomer acids with a polyamine.

11. The method of claim 10 wherein said polyamine comprises at least one member selected from the group of ethylenediamine, diethylenetriamine, triethylenetetraamine, tetraethylene pentaamine and aminoethylpiperazine.

12. The method of claim 10 wherein said tackifying compound has been quaternized.

13. The method of claim 5 wherein said particulate comprises at least one member selected from the group consisting of sand, ceramic particles, resin coated sand, hardened resin beads, sintered bauxite, metal particles and glass particles.

18. The method of claim 10 wherein said tackifying compound comprises a liquid or solution of a polyamide.

14. A method of treating a subterranean formation penetrated by a wellbore to control fines migration to said wellbore comprising the steps of:

providing a fluid suspension including a mixture of a particulate material and another material selected from the group of particles comprising metal, natural or synthetic polymers, ceramics and glass which are at least partially coated with an effective amount of a liquid or solution of a tackifying compound;

introducing the fluid suspension into a subterranean formation through a wellbore;

depositing the fluid suspension in the formation; and

flowing back fluid from the formation through the tackifying compound coated material whereby the tackifying compound material retards movement of at least a portion of any fine particulate material moving to said wellbore from the formation by adhering said fines to said coated particulate.

15. The method of claim 14 wherein said another material is in the form of fibers, beads, ribbons, flakes, platelets or shavings.

16. The method of claim 14 wherein said another material is present in an amount of from about 0.1 to about 5% by weight of the particulate material.

17. The method of claim 14 wherein said tackifying compound is present in an amount of from about 0.05 to about 3% by weight of said particulate.

19. The method of claim 14 wherein said tackifying compound comprises predominately a condensation reaction product of a dimer acid containing some trimer and higher oligomers and some monomer acids and a polyamine.

20. The method of claim 14 wherein said tackifying compound at least one member selected from the group of a liquid or solution of a polyester, a polycarbonate, a polycarbamate and a natural resin.