Methods of recovering a hydrocarbon material contained within a subterranean formation, and related working fluids

Patent metadata

Field	Value
Publication number	US-2016115372-A1
Application number	US-201414520993-A
Country	US
Kind code	A1
Filing date	Oct 22, 2014
Priority date	Oct 22, 2014
Publication date	Apr 28, 2016
Grant date	—

Abstract

A method of recovering a hydrocarbon material from a subterranean formation comprises forming a working fluid comprising substantially solid particles and an at least partially gaseous base material, the substantially solid particles exhibiting a greater heat capacity than the at least partially gaseous base material. The working fluid is introduced into a subterranean formation containing a hydrocarbon material to heat and remove the hydrocarbon material from the subterranean formation. An additional method of recovering a hydrocarbon material from a subterranean formation, and a working fluid are also described.

First claim

What is claimed is:

1 . A method of recovering a hydrocarbon material from a subterranean formation, comprising:
forming a working fluid comprising substantially solid particles and an at least partially gaseous base material, the substantially solid particles exhibiting a greater heat capacity than the at least partially gaseous base material; and introducing the working fluid into a subterranean formation containing a hydrocarbon material to heat and remove the hydrocarbon material from the subterranean formation.

2 . The method of claim 1 , wherein forming a working fluid comprises forming the substantially solid particles to have a heat capacity greater than or equal to about 0.1 kJ/kg-K.

3 . The method of claim 2 , wherein forming the solid particles comprises forming the substantially solid particles to comprise at least one of graphite, graphene, fullerenes, diamond, nanofibers, clay, inorganic material, an organo-silicon material, and metal.

4 . The method of claim 3 , wherein forming the solid particles further comprises forming the substantially solid particles to comprise a core of a first material at least partially surrounded by a shell of a second material.

5 . The method of claim 1 , wherein forming a working fluid comprises forming the substantially solid particles to have a thermal conductivity of greater than or equal to about 50 W/m-K.

6 . The method of claim 1 , wherein forming a working fluid comprises modifying surfaces of at least some of the substantially solid particles to maintain a substantially stable dispersion of the substantially solid particles within the at least partially gaseous base material.

7 . The method of claim 1 , Wherein forming a working fluid comprises modifying surfaces of at least some of the substantially solid particles to exhibit surfactant characteristics.

8 . The method of claim 1 , Wherein forming a working fluid comprises forming the substantially solid particles to be hydrophilic, hydrophobic, amphiphilic, oxophilic, lipophilic, oleophilic, or a combination thereof.

9 . The method of claim 1 , wherein forming a working fluid comprises forming the substantially solid particles to exhibit a surface area within a range of from about 300 m 2 /g to about 1800 m 2 /g.

10 . The method of claim 1 , wherein forming a working fluid comprises forming the working fluid to comprise from about 0.05 percent by weight to about 20.0 percent by weight of the substantially solid particles.

11 . The method of claim 1 , wherein introducing the working fluid into a subterranean formation comprises introducing the working fluid into the subterranean formation at a temperature of greater than or equal to about 100° C.

12 . A method of recovering a hydrocarbon material from a subterranean formation, comprising:
forming nanoparticles comprising at least one of graphite, graphene, fullerenes, diamond, nanofibers, clay, inorganic material, an organo-silicon material, and metal; combining the nanoparticles with an at least partially gaseous base material comprising at least one of steam and carbon dioxide to form a working fluid; and injecting the working fluid into a subterranean formation at a temperature greater than or equal to about 100° C. to heat and remove a hydrocarbon material contained within the subterranean formation.

13 . The method of claim 12 , wherein forming nanoparticles comprises formulating the nanoparticles to remain substantially solid up to a temperature of at least about 350° C.

14 . The method of claim 12 , wherein forming nanoparticles comprises attaching functional groups to surfaces of at least some of the nanoparticles.

15 . The method of claim 12 , wherein forming nanoparticles comprises forming the nanoparticles to have a heat capacity of greater than or equal to about 0.1 kJ/kg-K, and to have a thermal conductivity of greater than or equal to about 50 W/m-K.

16 . The method of claim 12 , wherein combining the nanoparticles with a base material further comprises combining the nanoparticles with at least one of a surfactant and a filler material.

17 . A working fluid, comprising:
an at least partially gaseous base material; and substantially solid particles dispersed and stabilized within the at least partially gaseous base material, the substantially solid particles each formulated to remain substantially solid up to a temperature of at least about 350° C. and each independently having a heat capacity of greater than or equal to about 0.1 kJ/kg-K.

18 . The method of claim 17 , wherein the at least partially gaseous base material comprises at least one of steam and carbon dioxide.

19 . The method of claim 17 , wherein the substantially solid particles each independently have a thermal conductivity of greater than or equal to about 50 W/m-K.

20 . The method of claim 17 , wherein at least some of the substantially solid particles comprise functional groups attached to surfaces thereof.

Assignees

• Baker Hughes Inc

Inventors

• Chakraborty Soma
• Johnson Michael H

Classifications

• C09K2208/10

  Nanoparticle-containing well treatment fluids · CPC title

• E21B43/24

  using heat, e.g. steam injection · CPC title

• C09K2208/08

  Fiber-containing well treatment fluids · CPC title

• C09K8/592 Primary

  Compositions used in combination with generated heat, e.g. by steam injection · CPC title

• C09K5/08 Primary

  Materials not undergoing a change of physical state when used (C09K5/16, C09K5/20 take precedence) · CPC title