Method for chemically treating hydrocarbon fluid in a downhole wellbore

• US 9,097,094 B1
• Filed: 07/23/2013
• Issued: 08/04/2015
• Est. Priority Date: 01/06/2012
• Status: Active Grant

• Current Assignee: Cavin B. Frost
• Original Assignee: Cavin B. Frost
• Inventors: Frost, Cavin B.
• Primary Examiner(s): Neuder, William P
• Application Number:
  US13/949,145
• Time in Patent Office: 742 Days
• US Class Current: 1/1
• CPC Class Codes: E21B 37/06 using chemical means for preventing or limiting , e.g. eliminating, the deposition of paraffins or like substances

Abstract

A method for downhole delivering of chemicals to a wellbore at the level of a hydrocarbon-bearing formation using an assembly formed form a blank tubular with first and second perforation sections, a no-flow nipple connected on one end and a bull plug connected on the other end, wherein the chemical is in solid phase, and slowly dissolves when exposed to wellbore fluids forming a method that can be repeated with the same equipment but additional charges of chemical.

Claims

1. A method for chemically treating a hydrocarbon fluid in a downhole wellbore, comprising:

a. forming a downhole chemical treatment assembly, the downhole chemical treatment assembly comprising;

(i) a blank tubular having a first end, a second end, a central axis and an outer diameter, and wherein the blank tubular consists of;

1. an upper blank tubing section;

2. a first perforated section with a plurality of first perforations in series with the upper blank tubing section;

3. a middle blank tubing section formed adjacent the first perforated section;

4. a second perforated section formed in series with the middle blank tubing section having a plurality of second perforations, wherein 200 percent to 2000 percent more second perforations are formed than first perforations; and

5. a lower blank tubing section formed adjacent the second perforated section;

(ii) an upper collar secured around the first end with an upper collar outer diameter;

(iii) a lower collar secured around the second end with a lower collar diameter, and each collar has an outer diameter larger than the blank tubular outer diameter;

(iv) a dissolving solid chemical treating material filling the blank tubular from the upper blank tubing section to the lower blank tubing section, comprising a chemical adapted to dissolve upon contact with the hydrocarbon fluid from the downhole wellbore to treat a member of the group comprising;

1. carbonate scale buildup;

2. chloride scale buildup;

3. iron scale buildup;

4. paraffin buildup;

5. corrosion;

6. asphaltene buildup; and

7. combinations thereof;

(v) a first tubular filtering screen encircling the first perforated section, wherein the first tubular filtering screen comprises;

1. a plurality of longitudinally oriented first ribs disposed around the central axis; and

2. a continuous wrapped first wire wound around the longitudinally oriented first ribs forming a plurality of first slots between the continuous wrapped first wire, and the first slots are dimensioned to control a rate of dissolution of the dissolving solid chemical treating material though the first slots while forming a first annulus between the continuous wrapped first wire and the first perforated section;

(vi) a second tubular filtering screen encircling the second perforated section, the second tubular filtering screen comprising;

1. a plurality of longitudinally oriented second ribs and disposed around the central axis; and

2. a continuous wrapped second wire wound around the longitudinally oriented second ribs forming a plurality of second slots, and the second slots are dimensioned to control a rate of dissolution of the dissolving solid chemical treating material through the second slots while forming a second annulus between the continuous wrapped second wire and the second perforated section;

(vii) a plurality of weld rings, wherein each weld ring secures an end of one of the tubular filtering screens;

(viii) a no-flow nipple secured to the upper collar to seal the downhole chemical treatment assembly; and

(ix) a bull plug secured to the lower collar to seal the downhole chemical treatment assembly;

b. attaching the formed downhole chemical treatment assembly to a member of the group consisting of;

tubing to be run into the well bore;

a bottom hole assembly for running into a wellbore;

a wireline for running into a wellbore;

a sand screen filter intake for use in a wellbore;

a gas separator for use in a wellbore;

a perforated lifting sub;

or a seating nipple for use in a wellbore;

c. running the attached downhole chemical treatment assembly into the wellbore;

d. securing the downhole chemical treatment assembly to a member of the group consisting of;

a perforating lifting subs, a sand screen filter intake, a gas separator, a seating nipple;

an electric submersible pump (ESP), a plunger lift, a jet pump, a gas lift, and combinations thereof;

which have been run into the wellbore after the downhole chemical treatment assembly; and

e. allowing well fluid to penetrate slots of the tubular filtering screens and dissolve the dissolving solid chemical treating material of the downhole chemical treatment assembly at a dissolution rate from 10 ppm to 180 ppm into the hydrocarbon fluid.

2. The method of claim 1, further comprising removing the downhole chemical treatment assembly from the wellbore after the preset, prior to time expiring, and reloading dissolving solid chemical treating material into the downhole chemical treatment assembly for reuse in another wellbore or in the same wellbore.

3. The method of claim 1, comprising inserting a sealing disc positioned inside the lower collar providing a redundant seal with the bull plug.

4. The method of claim 1, further comprising forming first threads on the upper blank tubing section for connecting the upper collar to the blank tubular.

5. The method of claim 1, further comprising forming bottom threads on the no-flow nipple collar for engaging the no-flow nipple with the upper collar.

6. The method of claim 1, further comprising forming second threads on the lower blank tubing section for engaging the lower collar to the blank tubular.

7. The method of claim 1, further comprising forming bull plug threads for engaging the lower collar with the bull plug.

8. The method of claim 1, further comprising using in the blank tubular:

pellets, discs with holes or solid centers;

or a plurality of solid cylindrical sticks of the dissolving solid chemical treating material.

9. The method of claim 1, using the bull plug with a bull plug outer diameter identical to a lower collar outer diameter.

10. The method of claim 1, further comprising welding the continuous wrapped first wire and the continuous wrapped second wire to the longitudinally oriented first ribs and the longitudinally oriented second ribs.

11. The method of claim 1, further comprising inserting a membrane between a third tubular filtering screen and a third perforated section in a second blank tubular, for slowly dissolving over a period of days, allowing a timed access to the dissolving solid chemical treating material to dissolve a member selected from the group:

a. carbonate scale buildup;

b. chloride scale buildup;

c. iron scale buildup;

d. paraffin buildup;

e. corrosion;

f. asphaltene buildup; and

g. combinations thereof.

12. The method of claim 11, further comprising using a second blank tubular with a retention nipple that permits fluid flow, and prevents the chemical from exiting the tubing during installation, the second blank tubular connects to the first blank tubular without using the no-flow nipple of the first blank tubular, and forming an extended assembly of two connected blank tubulars, the second blank tubular comprising:

a. a second blank tubular upper blank tubing section;

b. a second blank tubular perforated section with a plurality of second blank tubular perforations;

c. a second blank tubular lower blank tubing section adjacent the second blank tubular perforated section;

d. a second blank tubular upper collar secured around a first end of the second blank tubular;

e. a second blank tubular lower collar secured around a second end of the second blank tubular with each collar having an outer diameter slightly larger than the outer diameter of the second blank tubular;

f. a dissolving solid chemical treating material filling the second blank tubular;

g. a second blank tubular filtering screen encircling the second blank tubular perforated section, the second blank tubular filtering screen comprising;

(i) a plurality of longitudinally oriented second blank tubular ribs; and

(ii) a second blank tubular continuous wrapped wire wound around the longitudinally oriented second blank tubular ribs forming a plurality of second blank tubular slots between the second blank tubular continuous wrapped wire, the slots dimensioned to control a rate of dissolution of the dissolving solid chemical treating material though the slots while forming an annulus between the second blank tubular continuous wrapped wire and the second blank tubular perforated section; and

h. a no-flow nipple connected to the second blank tubular upper collar, the no-flow nipple seals off the assembly and connects to oil field equipment for receiving production fluids from the wellbore.

13. The method of claim 1, using a through opening to provide an indicator that the no-flow nipple acts as a plug.

14. The method of claim 1, further comprising using an end piece that replaces the no-flow nipple to engage the upper collar, the end piece comprising an intake end, a plurality of through ports formed in a wall of the end piece, the through ports and the intake end allowing fluid to flow into the blank tubular, the end piece also has a plug end for preventing fluid entering the blank tubular, and the end piece has a first orientation for engaging the blank tubular for flowing fluid into the blank tubular, and a second orientation engaging the blank tubular for preventing fluid from entering the blank tubular.

15. The method of claim 1, further comprises forming slots with widths from 0.006 inches to 0.075 inches to control a rate of dispersion of the dissolving solid chemical treating material.

16. The method of claim 1, further comprises using perforated tubing sections having lengths from 1 foot to 10 feet.

17. The method of claim 1, further comprising using a dissolving solid chemical treating material that inhibits bacteria growth in the blank tubular.

18. The method of claim 1, further comprising forming no-flow nipple upper threads on the no-flow nipple to secure the no-flow nipple to oil field equipment for receiving production fluids from the wellbore.

19. The method of claim 18, further comprising using a solid no-flow nipple for preventing fluid flowing into or out of the blank tubular.