Enhanced propped fracture conductivity in subterranean wells

Patent metadata

Field	Value
Publication number	US-11041111-B2
Application number	US-201616089936-A
Country	US
Kind code	B2
Filing date	Jun 23, 2016
Priority date	Jun 23, 2016
Publication date	Jun 22, 2021
Grant date	Jun 22, 2021

Abstract

A variety of systems, methods and compositions are disclosed, including, in one method, a method may comprise providing a proppant-free fracturing fluid; providing a proppant composition, wherein the proppant composition comprises proppant particulates and degradable thermoplastic particulates; introducing the proppant-free fracturing fluid into a subterranean formation at an injection rate above a fracture gradient to create or enhance at least one fracture in the subterranean formation; introducing the proppant composition into the at least one fracture; and allowing the proppant composition to form a proppant pack in the fracture, wherein the degradable thermoplastic particulates are degradable to generate voids in the proppant pack.

First claim

What is claimed is:

1. A method comprising:
providing a proppant-free fracturing fluid;
providing a proppant composition, wherein the proppant composition comprises proppant particulates and degradable thermoplastic particulates, wherein the degradable thermoplastic particulates comprise at least one of methyl methacrylate copolymer, polypropylene, polymethyl methacrylate, polyphenylene oxide, ethylene copolymer, propylene copolymer, polypropylene carbonate, ethylene interpolymer, propylene interpolymer, styrene interpolymer, and combinations thereof, wherein the proppant has a particle size of about 4 to about 100 mesh, wherein the degradable thermoplastic particulates have a multi modal particle size distribution;
introducing the proppant-free fracturing fluid into a subterranean formation at an injection rate above a fracture gradient to create or enhance at least one fracture in the subterranean formation; introducing the proppant composition into the at least one fracture, wherein the proppant composition is in a carrier fluid in an amount of about 0.1 pounds per gallon to about 10 pound per gallon of the carrier fluid;
allowing the proppant composition to form a proppant pack in the at least one fracture;
contacting the degradable thermoplastic particulates with liquid hydrocarbons produced from the subterranean formation and degrading the degradable thermoplastic particulates with the liquid hydrocarbons, wherein the degradable thermoplastic particulates are degraded to generate voids in the proppant pack.

2. The method of claim 1 , wherein the proppant composition further comprises at least one binding agent selected from the group consisting of a curable resin, a tackifying agent, or a combination thereof.

3. The method of claim 2 , wherein the curable resin comprises at least one resin selected from the group consisting of an epoxy resin, a two component epoxy based resins, novolak resins, polyepoxide resins, phenol-aldehyde resins, urea-aldehyde resins, urethane resins, phenolic resins, furan resins, furan alcohol resins, furfuryl alcohol resins, phenolic/latex resins, phenol formaldehyde resins, polyester resins and hybrids and copolymers thereof, polyurethane resins and hybrids and copolymers thereof, acrylate resins, and combinations thereof.

4. The method of claim 1 , wherein the proppant composition is introduced into the at least one fracture in a carrier fluid selected from the group consisting of aqueous fluids, non-aqueous fluids, slickwater fluids, aqueous gels, viscoelastic surfactant gels, foamed gels, emulsions, and combinations thereof.

5. The method of claim 1 , further comprising isolating with a plug an interval of interest before the injecting the proppant-free fracturing fluid.

6. The method of claim 1 , wherein the degradable thermoplastic particulates further comprise polystyrene and/or styrene methacrylate copolymer.

7. The method of claim 1 , wherein the degradable thermoplastic particulates have an average diameter from about 0.001 mm to about 10 mm.

8. The method of claim 1 , further comprising introducing additional degradable thermoplastic particulates to form a diverting plug in at least one flow path to divert subsequently introduced fluids to another flow path, wherein the degradable thermoplastic particulates in the diverting plug are multi-modal in particle size.

9. The method of claim 8 , wherein the diverting plug is formed in a perforation such that the subsequently introduced fluids forms one or more new primary fractures in the subterranean formation.

10. A method comprising:
introducing a proppant-free fracturing fluid into a subterranean formation at an injection rate above a fracture gradient to create or enhance at least one fracture in the subterranean formation;
introducing a fracturing fluid comprising proppant and polystyrene particles into the at least one fracture, wherein the polystyrene particles have a particle size of 100 microns or less, wherein the proppant composition is in the fracturing fluid in an amount of about 0.1 pounds per gallon to about 10 pound per gallon of the fracturing fluid;
forming a proppant pack comprising the proppant and polystyrene particles in the at least one fracture; and
degrading at least a portion of the polystyrene particles to generate voids in the proppant pack.

11. The method of claim 10 , wherein the polystyrene particles have a particle size distribution where about 20-25% by weight of the polystyrene particles have a particle size of about 4 to about 10 mesh and about 50% by weight of the polystyrene particles have a particle size of about 20 to about 40 mesh.

12. The method of claim 10 , further comprising introducing a proppant-free fracturing fluid comprising polystyrene particles into a first location and forming a diverter plug at the first location and diverting at least a portion of the proppant-free fracturing fluid comprising polystyrene particles to a second location.

13. The method of claim 10 , wherein the step of degrading comprises contacting the polystyrene particles with a liquid hydrocarbon in the wellbore.

Assignees

• Halliburton Energy Services Inc

Inventors

• Nguyen Philip D
• Vo Loan K
• Lahman Matthew Lewis

Classifications

• C09K8/40 Primary

  Spacer compositions, e.g. compositions used to separate well-drilling from cementing masses · CPC title

• C09K2208/30

  Viscoelastic surfactants [VES] · CPC title

• C09K8/66

  Compositions based on water or polar solvents (C09K8/64 takes precedence) · CPC title

• C09K8/805

  Coated proppants · CPC title

• C09K8/601

  using spacer compositions · CPC title