Mixing and Injecting Fiber-based Stimulation Fluids

Patent metadata

Field	Value
Publication number	US-2016108697-A1
Application number	US-201414516574-A
Country	US
Kind code	A1
Filing date	Oct 16, 2014
Priority date	Oct 16, 2014
Publication date	Apr 21, 2016
Grant date	—

Abstract

An emulsion is mixed with fibers while the emulsion is moving through a surface tubing using a venturi. The fiber/emulsion mixture is injected into a pressurized tank and the pressurized fiber/emulsion mixture is injected from the pressurized tank into a desired location in a wellbore. Pumps and pressure boosters may be used to move the fluid. Alternatively, an emulsion and a fiber suspension is provided and a first downhole tubing disposed in a wellbore conveys the emulsion downhole while a second downhole tubing disposed in the wellbore and circumferentially enclosing all or part of the first downhole tubing conveys the fiber suspension downhole. The first downhole tubing has nozzles through which the emulsion passes into the second downhole tubing and the emulsion and the fiber suspension mix. The mixture exits the second downhole tubing through ports at a desired location in the wellbore.

First claim

What is claimed is:

1 . A method, comprising:
moving an emulsion through a tubing; mixing fibers with the emulsion while the emulsion is moving through the tubing; injecting the fiber/emulsion mixture into a pressurized tank; and injecting the pressurized fiber/emulsion mixture into a desired location in a wellbore.

2 . The method of claim 1 , wherein moving the emulsion comprises using a first pump.

3 . The method of claim 1 , wherein mixing the fibers comprises using a venturi.

4 . The method of claim 1 , wherein injecting the fiber/emulsion mixture into a pressurized tank comprises using a second pump, with or without a pressure booster.

5 . The method of claim 1 , further comprising disposing a moveable spacer in the pressurized tank and injecting a pressurized fluid into the pressurized tank on one side of the moveable spacer.

6 . An apparatus, comprising:
a source of emulsion and a source of fiber; a surface tubing to convey the emulsion or an emulsion/fiber mixture, at least a portion of the surface tubing forming a venturi in which the fiber is mixed with the emulsion; one or more fluid displacement devices that move the emulsion and/or the emulsion/fiber mixture through the surface tubing; a pressurized tank that receives and discharges the emulsion/fiber mixture; and a downhole tubing that delivers the emulsion/fiber mixture to a desired location in a wellbore.

7 . The apparatus of claim 6 , wherein the one or more fluid displacement devices are selected from the group consisting of a low pressure pump, a high pressure pump, a progressive cavity pump, and a pressure booster.

8 . The apparatus of claim 6 , further comprising a spacer disposed within the pressurized tank and partitioning the interior volume of the pressurized tank.

9 . An apparatus, comprising:
a source of emulsion and a source of a fiber suspension; a first downhole tubing disposed in a wellbore to convey the emulsion, the first downhole tubing having one or more nozzles; and a second downhole tubing disposed in the wellbore and circumferentially enclosing all or part of the first downhole tubing to convey the fiber suspension, the second downhole tubing having one or more ports; wherein the emulsion and the fiber suspension are mixed within the interior of the second downhole tubing.

10 . The apparatus of claim 9 , wherein the second downhole tubing is selected from the group consisting of customized mixing tubing, production tubing, liners, and casing.

11 . The apparatus of claim 9 , wherein the emulsion is an oil/water or a water/oil emulsion and the fiber in the fiber suspension is suspended in a non-wetting fluid.

12 . The apparatus of claim 9 , wherein the first downhole tubing is selected from the group consisting of coil tubing, drill pipe, and production tubing.

13 . The apparatus of claim 9 , wherein the one or more nozzles provide fluid communication between the first downhole tubing and the second downhole tubing.

14 . The apparatus of claim 13 , wherein the one or more nozzles provide turbulence-induced mixing of the emulsion and the fiber suspension within the interior of the second downhole tubing.

15 . The apparatus of claim 9 , wherein the one or more nozzles further comprise a variable choke.

16 . The apparatus of claim 9 , wherein the one or more ports provide fluid communication between the second downhole tubing and an annulus of the wellbore or the second downhole tubing and a surrounding formation.

17 . The apparatus of claim 9 , wherein the one or more ports may be selectably opened and/or closed.

18 . The apparatus of claim 17 , wherein the opening or closing of the one or more ports is controlled using a device selected from the group consisting of a hydraulic valve, an electric valve, and a sliding sleeve.

19 . The apparatus of claim 9 , further comprising a control probe.

20 . The apparatus of claim 19 , wherein the control probe is selected from the group consisting of a dielectric probe, a capacitance probe, and a resistivity probe.

21 . The apparatus of claim 9 , wherein the fibers in the fiber suspension are encapsulated in a degradable material.

22 . The apparatus of claim 9 , further comprising one or more packers in sealing engagement with the first downhole tubing and the second downhole tubing or the second downhole tubing and the wellbore wall.

23 . A method, comprising:
moving an emulsion in a first downhole tubing disposed in a wellbore; moving a fiber suspension in a second downhole tubing disposed in the wellbore and circumferentially enclosing all or part of the first downhole tubing; injecting the emulsion into the fiber suspension via one or more nozzles in the first downhole tubing, thereby producing a fiber/emulsion mixture in the interior of the second downhole tubing; and
injecting the fiber/emulsion mixture into a desired location in the wellbore via ports in the second downhole tubing.

Assignees

• Schlumberger Technology Corp

Inventors

• Abbad Mustapha
• Dyer Stephen John Remane

Classifications

• E21B43/26

  by forming crevices or fractures · CPC title

• E21B33/138 Primary

  Plastering the borehole wall; Injecting into the formation · CPC title

• E21B17/00

  Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; {Cables;} Casings; Tubings · CPC title

• E21B41/0078

  Nozzles used in boreholes (drilling by liquid or gas jets E21B7/18; drill bits with nozzles E21B10/60; perforators using direct fluid action E21B43/114; obtaining a slurry of minerals using nozzles E21B43/29) · CPC title

• E21B34/06

  in wells · CPC title