Method and apparatus for downhole in-situ mixing using dual, concentric flow channels

Patent metadata

Field	Value
Publication number	US-2024426181-A1
Application number	US-202318340694-A
Country	US
Kind code	A1
Filing date	Jun 23, 2023
Priority date	Jun 23, 2023
Publication date	Dec 26, 2024
Grant date	—

Abstract

A tool for use in a wellbore includes an annular body having an inner flow passage extending axially therethrough, at least one gripping member positioned around an outer perimeter of a retainer section of the annular body, and a gate member positioned in the inner flow passage. When the gate member is in a closed configuration, an upstream portion of the inner flow passage is sealed from a downstream portion of the inner flow passage by the gate member. When the gate member is in an open configuration, the upstream portion of the inner flow passage is fluidly connected to the downstream portion of the inner flow passage. At least one static mixing blade extends through the downstream portion of the inner flow passage to mix fluid when it flows through the open gate member.

First claim

1 . A tool for use in a wellbore, comprising:
an annular body, comprising;
an inner flow passage extending axially through the annular body; and
at least one gripping member positioned around an outer perimeter of a retainer section of the annular body;
an inner sleeve comprising an inner sleeve port formed therethrough, the inner sleeve movably positioned within the retainer section; a gate member positioned in the inner flow passage,
wherein, when the gate member is in a closed configuration, an upstream portion of the inner flow passage is sealed from a downstream portion of the inner flow passage by the gate member, and
wherein, when the gate member is in an open configuration, the upstream portion of the inner flow passage is fluidly connected to the downstream portion of the inner flow passage; and
at least one static mixing blade extending through the downstream portion of the inner flow passage.

2 . The tool of claim 1 , wherein the tool is made of drillable materials.

3 . The tool of claim 1 ,
wherein, when the inner sleeve port is in an open position, the inner sleeve port is fluidly connected to an outer flow passage formed through the retainer section.

4 . A method for sealing a downhole location in a wellbore, comprising:
setting an RMA tool at a location uphole of the downhole location, wherein the RMA tool comprises:
an annular body having an inner flow passage formed axially therethrough;
at least one gripping member positioned around an outer perimeter of a retainer section of the annular body;
an inner sleeve comprising an inner sleeve port formed therethrough, the inner sleeve movably positioned within the retainer section;
a gate member positioned in the inner flow passage,
wherein, when the gate member is in a closed configuration, an upstream portion of the inner flow passage is sealed from a downstream portion of the inner flow passage by the gate member, and
wherein, when the gate member is in an open configuration, the upstream portion of the inner flow passage is fluidly connected to the downstream portion of the inner flow passage; and

a static mixer section of the annular body having at least one static mixing blade extending through the downstream portion of the flow passage;
inserting an end of a dual path tubing into the retainer section of the RMA tool, wherein the dual path tubing has a first flow path concentrically positioned within a second flow path; opening the inner sleeve port in the inner sleeve to fluidly connect the second flow path with the static mixer section via an outer flow path formed through the retainer section and bypassing the gate member; pumping a first fluid in the first flow path through the retainer section of the RMA tool and through the gate member to the static mixer section; pumping a second fluid in the second flow path through the outer flow path of the retainer section of the RMA tool to the static mixer section; mixing the first fluid and the second fluid in the static mixer section to form a curing composition; filling the downhole location with a volume of the curing composition; allowing the curing composition to set; and removing the dual path tubing from the wellbore.

5 . The method of claim 4 , wherein the dual path tubing is formed by running coiled tubing inside a drill pipe string.

6 . The method of claim 4 , wherein the dual path tubing is formed by running a first tubing string inside a second tubing string.

7 . The method of claim 4 , wherein the dual path tubing comprises a top-entry sub positioned at an axial end of the dual path tubing.

8 . The method of claim 4 , wherein the dual path tubing is formed by nested dual drill pipe.

9 . (canceled)

10 . The method of claim 4 , further comprising opening a second gate member provided at an axial end of the dual path tubing to fluidly connect the first flow path of the dual path tubing to the inner flow passage through the RMA tool.

11 . The method of claim 4 , wherein the dual path tubing comprises a drillable injection sub connected at an axial end of the dual path tubing via a ball drop disconnect or a hydraulic disconnect.

12 . The method of claim 4 , wherein the first fluid comprises:
one or more of an epoxy resin, an acidic nanosilica dispersion, an alkaline nanosilica dispersion, a portland cement, and an acid soluble magnesia cement.

13 . The method of claim 4 , wherein the second fluid comprises:
one or more of a curing agent, a chemical activator, a salt solution, and a gelling agent.

14 . The method of claim 4 , wherein mixing the first fluid and the second fluid in the static mixer section to form a curing composition occurs in a time ranging from 1 to 3 minutes.

15 . The method of claim 4 , wherein pumping the second fluid in the second flow path further comprises:
pumping the second fluid at a variable rate in time, wherein pumping the second fluid begins at a minimum flow rate of the second fluid and increases linearly until reaching a maximum flow rate of the second fluid; wherein a maximum reaction rate of the first fluid with the second fluid is estimated from a maximum potential well temperature; wherein a lower limit of a concentration of the second fluid is estimated from the maximum reaction rate; and wherein the lower limit of the concentration of the second fluid is used to calculate the minimum flow rate of the second fluid.

16 . A system for sealing a section of a well, comprising:
a dual path tubing extending into the well from surface equipment at an opening of the well; an RMA tool connected at an axial end of the dual path tubing, the RMA tool comprising:
an annular body having an inner flow passage formed axially therethrough;
a retainer section of the annular body comprising:
at least one gripping member positioned around an outer perimeter of the retainer section of the annular body;

an inner sleeve comprising an inner sleeve port formed therethrough, the inner sleeve movably positioned within the retainer section;
a gate member positioned in the inner flow passage,
wherein, when the gate member is in a closed configuration, an upstream portion of the inner flow passage is sealed from a downstream portion of the inner flow passage by the gate member, and
wherein, when the gate member is in an open configuration, the upstream portion of the inner flow passage is fluidly connected to the downstream portion of the inner flow passage; and

a static mixer section of the annular body having at least one static mixing blade extending through the downstream portion of the flow passage.

17 . The system of claim 16 , wherein a first flow path of the dual path tubing is fluidly connected to the inner flow passage of the retainer section, and wherein a second flow path of the dual path tubing is fluidly connected to an outer flow passage formed through the retainer section.

18 . The system of claim 16 ,
wherein, when the inner sleeve port is in an open position, the second flow path of the dual path tubing is fluidly connected to the outer flow passage of the retainer section.

19 . The system of claim 16 , further comprising a first fluid source and a second fluid source provided at a surface location of a well, wherein the first fluid source is fluidly connected to a first flow path of the dual path tubing and the second fluid source is fluidly connected to a second flow path of the dual path tubing.

20 . The system of claim 16 , wherein the dual path tubing comprises an inner tubi

Assignees

• Saudi Arabian Oil Co

Inventors

• Shaarawi Amjad
• Alsheikh Mohammed
• Aljohar Abdulwahab
• Al-Yami Abdullah
• Wagle Vikrant
• Alkhalaf Sara Abdulaziz
• Lindahl Carl Daniel

Classifications

• E21B21/10

  Valve arrangements in drilling-fluid circulation systems · CPC title

• E21B2200/05

  Flapper valves · CPC title

• E21B2200/06

  Sleeve valves · CPC title

• E21B33/13

  Methods or devices for cementing, for plugging holes, crevices or the like · CPC title

• E21B27/02

  Dump bailers, i.e. containers for depositing substances, e.g. cement or acids · CPC title