Downhole assembly for treating wellbore components, and method for treating a wellbore
View Patent ↗A downhole assembly for delivering chemical treatment to a wellbore at the level of a hydrocarbon-bearing formation is provided. The chemical treatment is in solid phase, and slowly dissolves when exposed to wellbore fluids. A method of treating a wellbore using a solid chemical is also provided.
1. A downhole assembly for delivering chemical treatment to a wellbore, comprising:
a first tubular body;
a second tubular body residing substantially concentrically within the first tubular body, the second tubular body being porous to provide fluid communication between the first tubular body and a bore within the second tubular body;
an annular region between the second tubular body and the surrounding first tubular body;
a chemical treating material, wherein:
the chemical treating material is in solid phase but is dissolvable upon contact with a wellbore fluid and is designed to (i) inhibit a build-up of precipitate on components in the wellbore, (ii) remove scale on components in the wellbore, (iii) prevent a build-up of bacteria in the wellbore, (iv) prevent a build-up of paraffin in the wellbore, or (v) combinations thereof;
the chemical treating material resides within either a bore of the second tubular body or the annular region around the second tubular body; and
the chemical treating material is a continuous solid material in the shape of one or more discs; and the discs reside in the annular region between the second tubular body and the surrounding first tubular body; and
the second tubular body is a perforated tubing; and the surrounding first tubular body is a wire-wrapped screen having slots dimensioned to control a rate of dissolution of the solid chemical treating material.
2. The downhole assembly of claim 1 , wherein the solid chemical treating material comprises one or more discs having a first rate of dissolution, and one or more discs having a second rate of dissolution that is slower than the first rate of dissolution, with the discs being stacked in the annular region.
3. The downhole assembly of claim 1 , wherein:
the second tubular body defines a screen having slots;
the first tubular body defines a blank pipe; and
the downhole assembly further comprises:
an upper perforated tubular section having a bore, the bore being in fluid communication with the bore of the screen, and the upper perforated tubular being operatively connected to a first end of the screen;
a lower perforated tubular section having a bore, the bore also being in fluid communication with the bore of the screen, and the lower perforated tubular body being operatively connected to a second opposite end of the screen.
4. The downhole assembly of claim 1 , wherein the downhole assembly is sealed at opposing ends.
5. The downhole assembly of claim 1 , wherein: the chemical treating material is a continuous solid material in the shape of one or more cylinders; and the cylinders reside in the bore of the second tubular body.
6. The downhole assembly of claim 5 , wherein: the second tubular body is a perforated tubing; and the surrounding first tubular body is a wire-wrapped screen having slots dimensioned to control a rate of dissolution of the solid chemical treating material.
7. The downhole assembly of claim 6 , wherein the solid chemical treating material comprises one or more cylinders having a first rate of dissolution and one or more cylinders having a second rate of dissolution that is slower than the first rate of dissolution.
8. The downhole assembly of claim 6 , wherein the assembly resides within a wellbore below a downhole pump.
9. The downhole assembly of claim 6 , further comprising: a bull plug at a lower end of the screen to seal the lower end of the downhole assembly to fluid flow.
10. The downhole assembly of claim 6 , further comprising: a no-flow nipple or a collar with a blank plate at an upper end of the downhole assembly to seal the upper end of the downhole assembly to fluid flow.
11. The downhole assembly of claim 6 , further comprising: a section of blank tubing disposed at an end of the second tubular body and having a bore that is in fluid communication with the bore of the second tubular body; wherein the bore of the section of blank pipe contains one or more cylinders of the chemical treating material.
12. The downhole assembly of claim 5 , wherein:
the second tubular body comprises a first perforated section and a second perforated section;
the surrounding first tubular body comprises a wire-wrapped screen having slots dimensioned to control a rate of dissolution of the solid chemical treating material, with a first portion of wire-wrapped screen being placed around the first perforated section, and a second portion of wire-wrapped screen being placed around the second perforated section;
the downhole assembly further comprises a section of blank tubing disposed between the first perforated section and the second perforated section;
the section of blank tubing, the first perforated section and the second perforated section are all part of a same joint of tubing sharing a same bore, with the bore containing one or more cylinders of the solid chemical treating material.
13. A downhole assembly for delivering chemical treatment to a wellbore, comprising:
a first tubular body defining a wire-wrapped screen;
a second tubular body residing substantially concentrically within the first tubular body, the second tubular body defining a section of perforated tubing that provides fluid communication between the first tubular body and a bore within the second tubular body;
a plug at a lower end of the second tubular body providing a fluid seal to a bottom of the downhole assembly;
a first section of blank pipe disposed at an upper end of the second tubular body and having a bore that is in fluid communication with the bore of the second tubular body; and
a chemical treating material, wherein:
the chemical treating material is in a solid phase but is dissolvable upon contact with a wellbore fluid and is designed to (i) inhibit a build-up of precipitate on components in the wellbore, (ii) remove scale and corrosion on components in the wellbore, (iii) prevent a build-up of bacteria in the wellbore, (iv) prevent a build-up of paraffin in the wellbore, or (v) combinations thereof;
the chemical treating material resides within the bore of the second tubular body and in the bore of the section of blank pipe; and
the chemical treating material is in the form of two or more substantially solid cylinders.
14. The downhole assembly of claim 13 , further comprising: a no-flow nipple or a collar with a blank disc at an upper end of the downhole assembly to seal the upper end of the downhole assembly.
15. The downhole assembly of claim 14 , wherein the assembly resides within a wellbore below a downhole pump.
16. The downhole assembly of claim 13 , wherein the solid chemical treating material comprises one or more cylinders having a first rate of dissolution and one or more cylinders having a second rate of dissolution that is slower than the first rate of dissolution.
17. The downhole assembly of claim 16 , wherein the solid chemical treating material comprises one or more cylinders having a dissolvable membrane to delay dissolution of the solid chemical treating material.
18. The downhole assembly of claim 16 , wherein the wire-wrapped screen comprises slots dimensioned to control a rate of dissolution of the solid chemical treating material within the second tubular body.
19. The downhole assembly of claim 13 , wherein: the section of blank pipe and the second tubular body are part of a same joint of tubing sharing a same bore, with the bore containing one or more cylinders of the solid chemical treating material.
20. The downhole assembly of claim 19 , further comprising: a vent above the section of blank pipe, the vent comprising a section of perforated tubing forming a bore, and a wire-wrapped screen around the section of perforated tubing; and wherein the section of perforated tubing in the vent and the first section of blank pipe are part of a same joint of tubing sharing a same bore.
21. The downhole assembly of claim 20 , further comprising: a second section of blank pipe residing between a no-flow nipple or a collar with a blank disc, and the vent; and wherein the chemical treating material further resides within the bore of the perforated tubing within the vent.
22. A method of treating a wellbore using a solid treating material, comprising:
running a downhole assembly into a wellbore, the downhole assembly comprising:
a first tubular body;
a second tubular body residing substantially concentrically within the first tubular body, the second tubular body being porous to provide fluid communication between the first tubular body and a bore within the second tubular body;
an annular region between the second tubular body and the surrounding first tubular body;
a chemical treating material, wherein:
the chemical treating material is in solid phase but is dissolvable upon contact with a wellbore fluid and is designed to (i) inhibit a build-up of precipitate on components in the wellbore, (ii) remove scale and corrosion on components in the wellbore, (iii) prevent a build-up of bacteria in the wellbore, (iv) prevent a build-up of wax or paraffin in the wellbore, or (v) combinations thereof;
the chemical treating material resides within either the second tubular body or the annular region around the second tubular body; and
the chemical treating material is a continuous solid material in the shape of one or more discs; and the discs reside in the annular region between the second tubular body and the surrounding first tubular body; and
the second tubular body is a perforated tubing; and the surrounding first tubular body is a wire-wrapped screen having slots dimensioned to control a rate of dissolution of the solid chemical treating material.
23. The method of claim 22 , wherein the solid chemical treating material comprises one or more discs having a first rate of dissolution and one or more discs having a second rate of dissolution that is slower than the first rate of dissolution, with the discs being stacked in the annular region.
24. The method of claim 22 , wherein: the chemical treating material is a continuous solid material in the shape of one or more cylinders; and the cylinders reside in the bore of the second tubular body.
25. The method of claim 24 , wherein: the second tubular body is a perforated tubing; and the surrounding first tubular body is a wire-wrapped screen having slots dimensioned to control a rate of dissolution of the solid chemical treating material.
26. The method of claim 25 , wherein the assembly resides within the wellbore below a downhole pump.
27. The method of claim 26 , wherein the solid chemical treating material comprises one or more cylinders having a first rate of dissolution and one or more cylinders having a second rate of dissolution that is slower than the first rate of dissolution.
28. The method of claim 25 , further comprising: a bull plug or a blank disc at a lower end of the screen to seal a lower end of the downhole assembly.
29. The method of claim 25 further comprising: a reversible no-flow nipple or a collar having a blank disc at an upper end of the downhole assembly to seal the upper end of the downhole assembly.
30. The method of claim 24 , further comprising: a section of blank pipe disposed at an end of the second tubular body and having a bore that is in fluid communication with the bore of the second tubular body; wherein the bore of the section of blank pipe contains one or more cylinders of the chemical treating material.
31. The method of claim 22 , further comprising: threadedly connecting the downhole assembly to the lower end of a seating nipple or a joint of production tubing as part of running the downhole assembly into the wellbore.
32. The method of claim 31 , further comprising: producing hydrocarbon fluids from the wellbore.
33. The method of claim 25 , further comprising: determining a slot width that correlates to a dissolution rate of the chemical treating material in the wellbore.
34. The method of claim 33 , wherein the slot width is between about 0.006 and 0.075 inches.
35. The method of claim 30 , wherein: the section of blank pipe is between about 2 and 20 feet (0.61 and 6.1 meters) in length; and the second tubular body is between about 6 inches and 10 feet (0.15 and 3.05 meters) in length.
36. The method of claim 35 , further comprising: providing one or more cylinders of solid chemical material having a first rate of dissolution; and providing one or more cylinders of solid chemical material having a second rate of dissolution that is slower than the first rate of dissolution.
37. The method of claim 36 , further comprising: placing at least one of the one or more cylinders having a first rate of dissolution in the bore of the second tubular body; and placing at least one of the one or more cylinders having a second rate of dissolution in the bore of the second tubular body.
38. The method of claim 30 , wherein: the second tubular body comprises a first perforated section and a second perforated section; the surrounding first tubular body comprises a wire-wrapped screen having slots dimensioned to control a rate of dissolution of the solid chemical treating material, with a first portion of wire-wrapped screen being placed around the first perforated section, and a second portion of wire-wrapped screen being placed around the second perforated section; the downhole assembly further comprises a section of blank tubing disposed between the first perforated section and the second perforated section; the section of blank tubing, the first perforated section and the second perforated section are all part of a same joint of tubing sharing a same bore, with the bore containing one or more cylinders of the solid chemical treating material.
39. The method of claim 38 , further comprising: a vent above the section of blank tubing, the vent comprising a section of perforated tubing forming a bore, and a wire-wrapped screen around the section of perforated tubing; and wherein the section of perforated tubing in the vent and the section of blank tubing are part of a same joint of tubing sharing a same bore.