Wellbore servicing materials and methods of making and using same

Patent metadata

Field	Value
Publication number	US-2016153273-A1
Application number	US-201314907232-A
Country	US
Kind code	A1
Filing date	Aug 23, 2013
Priority date	Aug 23, 2013
Publication date	Jun 2, 2016
Grant date	—

Abstract

A method of servicing a wellbore in a subterranean formation comprising placing in the wellbore and/or subterranean formation a pad fluid and forming a fracture in the subterranean formation, placing in the fracture a first slurry fluid comprising a reducible material and a first particulate material and in an alternating sequence a second slurry fluid and a spacer fluid, wherein the second slurry fluid comprises a second particulate material, allowing the fracture to close; and allowing the fluids to break and the reducible materials to degrade, wherein a particulate-laden proppant pack (PLPP) is formed.

First claim

What is claimed is:

1 . A method of servicing a wellbore in a subterranean formation comprising:
placing in the wellbore and/or subterranean formation a pad fluid and forming a fracture in the subterranean formation; placing in the fracture a first slurry fluid comprising a reducible material and a first particulate material; placing in the fracture, in an alternating sequence, a second slurry fluid and a spacer fluid, wherein the second slurry fluid comprises a second particulate material; allowing the fracture to close; and allowing the fluids to break and the reducible materials to degrade, wherein a particulate-laden proppant pack (PLPP) is formed.

2 . The method of claim 1 wherein the pad fluid and the spacer fluid are the same.

3 . The method of claim 1 wherein the first slurry fluid comprises the second slurry fluid and the reducible material.

4 . The method of claim 1 wherein a volumetric ratio between the first slurry fluid and the second slurry fluid is in the range of from about 4:1 to about 0.2:1.

5 . The method of claim 1 wherein the first particulate material and the second particulate material are the same.

6 . The method of claim 1 wherein the first particulate material comprises a plurality of first particulate material clusters.

7 . The method of claim 1 wherein the second particulate material comprises a plurality of second particulate material clusters.

8 . The method of claim 1 wherein the first particulate material and/or the second particulate material comprises a low-grade particulate material.

9 . (canceled)

10 . (canceled)

11 . The method of claim 8 wherein the low-grade particulate material comprises low-grade sand.

12 . (canceled)

13 . The method of claim 1 wherein the reducible material comprises at least one material selected from the group consisting of: a degradable polymer, a polymeric material, a hardened plastic, a rubber, any derivative thereof, and any combination thereof.

14 . The method of claim 13 wherein the degradable polymer is selected from the group consisting of: a polysaccharide; a lignosulfonate; a chitin; a chitosan; a protein; a proteinous material; a fatty alcohol; a fatty ester; a fatty acid salt; an orthoester; an aliphatic polyester; a poly(lactide); a poly(glycolide); a poly(ε-caprolactone); a polyoxymethylene; a polyurethane; a poly(hydroxybutyrate); a poly(anhydride); an aliphatic polycarbonate; a polyvinyl polymer; an acrylic-based polymer; a poly(amino acid); a poly(aspartic acid); a poly(alkylene oxide); a poly(ethylene oxide); a polyphosphazene; a poly(orthoester); a poly(hydroxy ester ether); a polyether ester; a polyester amide; a polyamide; a polyhdroxyalkanoate; a polyethyleneterephthalate; a polybutyleneterephthalate; a polyethylenenaphthalenate; and any copolymer, blend, derivative, or combination thereof.

15 . (canceled)

16 . (canceled)

17 . The method of claim 1 wherein the reducible material comprises a foamed reducible material.

18 . The method of claim 1 wherein the reducible material is present within the first slurry fluid in an amount of from about 0.1 wt. % to about 10 wt. %, based on the total weight of the first particulate material.

19 . The method of claim 1 wherein the alternating sequence comprises (i) placing a volume of the second slurry fluid in the wellbore and/or subterranean formation; (ii) placing a volume of the spacer fluid in the wellbore and/or subterranean formation; (iii) repeating (i) and (ii) until a sufficient amount of the second slurry fluid has been introduced to the wellbore and/or subterranean formation.

20 . (canceled)

21 . The method of claim 1 wherein the PLPP comprises (i) a mosaic structure and (ii) an effective length L f , wherein (a) a first proppant pack region spans across a far wellbore length L ff of a far wellbore region of the subterranean formation, and (b) a second proppant pack region spans across a near wellbore length L fn of a near wellbore region of the subterranean formation, wherein L ff is equal to or greater than about 35% of L f , wherein L fn is less than about 65% of L f , and wherein L f =L ff L fn .

22 . The method of claim 21 wherein the first proppant pack region comprises a plurality of first flow channels and the first particulate material wherein the first flow channels are uniformly distributed throughout the first proppant pack region.

23 . (canceled)

24 . A method of servicing a wellbore in a subterranean formation comprising:
placing in the wellbore and/or subterranean formation a pad fluid and forming a fracture in the subterranean formation; placing in the fracture a first slurry fluid comprising a reducible material and a plurality of low-grade sand clusters; placing in the fracture, in an alternating sequence, a second slurry fluid and a spacer fluid, wherein the second slurry fluid comprises a plurality of low-grade sand clusters, and wherein the pad fluid and the spacer fluid are the same; allowing the fracture to close; and allowing the fluids to break and the reducible materials to degrade, wherein a particulate-laden proppant pack is formed.

25 . The method of claim 24 wherein the first slurry fluid comprises the second slurry fluid and the reducible material.

26 . The method of claim 24 wherein the reducible material comprises foamed polylactic acid and/or polyglycolic acid further comprising an inorganic salt.

27 . A particulate-laden proppant pack (PLPP) disposed within a fracture of a subterranean formation, wherein the PLPP comprises (i) a mosaic structure and (ii) an effective length L f , wherein (a) a first proppant pack region spans across a far wellbore length L ff of a far wellbore region of the subterranean formation, and (b) a second proppant pack region spans across a near wellbore length L fn of a near wellbore region of the subterranean formation, wherein L ff is equal to or greater than about 35% of L f , wherein L fn is less than about 65% of L f , and wherein L f =L ff +L fn .

28 .- 42 . (canceled)

Assignees

• Halliburton Energy Services Inc

Inventors

• Nguyen Philip D
• Bryant Jason E

Classifications

• C09K2208/18

  Bridging agents, i.e. particles for temporarily filling the pores of a formation; Graded salts · CPC title

• C09K8/90

  of natural origin, e.g. polysaccharides, cellulose · CPC title

• C09K8/88

  macromolecular compounds · CPC title

• C09K8/805

  Coated proppants · CPC title

• C09K8/5758

  of natural origin, e.g. polysaccharides, cellulose (C09K8/5756 takes precedence) · CPC title