Method for monitoring gas lift wells using minimal concentration tracer materials

Patent metadata

Field	Value
Publication number	US-10030508-B2
Application number	US-201615229287-A
Country	US
Kind code	B2
Filing date	Aug 5, 2016
Priority date	Oct 15, 2015
Publication date	Jul 24, 2018
Grant date	Jul 24, 2018

Abstract

Evaluating annulus-tubing communication points in a production well having an annulus between a production string and a surrounding string(s) of casing. Determining a composition of production fluids produced from the well, and injecting one or more tracer materials into the annulus of the well under pressure as part of a lift gas. Each of the one or more tracer materials defines a material that is not native to the production fluids, and each has a different rate of diffusivity in the lift gas. The tracer materials are detected upon being produced at the surface. A mass spectrometer or other analyzer capable of detecting tracer materials at concentrations of less than 1,000 ppm is used. Determining injection points of the one or more tracer materials, and determining whether each of the injection points represents a gas lift valve along the production tubing.

First claim

What is claimed is:

1. A method for evaluating annulus-tubing communication points in a production well, the production well having one or more strings of casing extending below a surface, and a string of production tubing within the strings of casing thereby forming an annulus, and the method comprising:
placing up to 1,000 cc's of each of two or more tracer materials into a portable, hand-held vessel;
causing the two or more tracer materials to be injected from the vessel into the annulus of the well under pressure as part of a lift gas, wherein each of the two or more tracer materials defines a material that is not native to the production fluids;
further injecting the lift gas in order to cause each of the two or more tracer materials to contact the annulus-tubing communication points residing along the production tubing, and to enter the production tubing;
producing formation fluids along with lift gas and the two or more tracer materials to the surface;
detecting the two or more tracer materials at the surface by using a fluid analyzer, wherein the fluid analyzer is capable of detecting the two or more tracer materials at concentrations of less than 1,000 ppm; and
measuring a concentration of each of the two or more tracer materials in the produced fluids as a function of time.

2. The method of claim 1 , further comprising:
determining injection points of the two or more tracer materials into the production tubing; and
determining whether each of the injection points represents a gas lift valve along the production tubing.

3. The method of claim 2 , wherein determining injection points comprises:
determining an injection time of the two or more tracer materials;
determining a volume of the annulus between the production tubing and the well casing per unit of depth;
determining a flow rate of the lift gas supplied to the well;
determining a velocity of the lift gas in the wellbore; or
combinations thereof.

4. The method of claim 3 , wherein the communication points comprise open gas lift valves, holes in the production tubing, holes in gas lift valves, or combinations thereof.

5. The method of claim 3 , wherein determining whether each of the injection points represents a gas lift valve along the production tubing comprises:
reviewing architecture for the wellbore to identify existing gas lift valves;
determining an expected response time for each of the tracer materials, which would indicate that only an appropriate gas lift valve is open; and
determining whether the gas lift valves are operating properly by comparing actual response times of the at least one tracer materials to the expected response times.

6. The method of claim 5 , wherein:
the one or more tracer materials are gases at downhole temperatures and pressures; and
the method further comprises determining a composition of production fluids produced from the well.

7. The method of claim 5 , wherein the two or more tracer materials comprise Ar, N 2 , O 2 , SF 6 , He, Xe, or combinations thereof.

8. The method of claim 5 , wherein the fluid analyzer is a gas chromatograph or a mass spectrometer.

9. The method of claim 5 , wherein:
the two or more tracer materials comprise at least two tracer components; and
the method further comprises:
determining a rate of diffusivity of each of at least three tracer materials; and
comparing diffusivity rates of each of the at least two tracer components in the lift gas to (i) further identify gas lift valves; (ii) evaluate a geometry of each of the communication points, or (iii) both.

10. The method of claim 5 , wherein:
the one or more tracer materials comprise at least three tracer materials; and
each of the at least three tracer materials has a different rate of diffusivity within the lift gas.

11. The method of claim 10 , further comprising:
optimizing the fluid analyzer to detect each of the at least three tracer materials in the production fluids;
determining an expected concentration of each tracer material and corresponding return times, which would indicate the presence of an open gas lift valve in the wellbore; and
evaluating a geometry of the injection points by analyzing diffusivity and concentration of the tracer materials as a function of time.

12. The method of claim 11 , wherein:
the tubing-annulus contact points represent a plurality of gas lift valves spaced along the production tubing; and
the method further comprises:
determining which of a plurality of gas lift valves is passing the one or more tracer materials into the production tubing;
repeating the injection steps, the producing step, the detecting step, the determining step and the evaluating a geometry step a plurality of times over a period of time; and
comparing results of the evaluating a geometry step over the period of time to determine historical injection trends for the gas lift valves.

13. The method of claim 12 , further comprising:
replacing any gas lift valves that are determined to be defective based on the historical injection trends.

14. The method of claim 12 , further comprising:
adjusting selected gas lift valves based on the historical injection trends.

15. The method of claim 11 , wherein the evaluating a geometry step comprises inputting data into a program having computer executable instructions.

16. The method of claim 11 , wherein the wellbore is an extended length wellbore that traverses multiple zones across more than 3,000 feet of horizontal hole below the gas lift valves.

17. The method of claim 1 , wherein:
the vessel weighs less than 10 pounds, and
the method further comprises transporting the vessel to a well site of the production well.

18. The method of claim 17 , wherein:
the two or more tracer materials are gases at surface temperatures and pressures;
the total volume of the vessel is less than 1,000 cubic centimeters; and
the vessel defines a single-use or reusable gas bottle, or a gas cartridge.

19. The method of claim 1 , wherein:
the two or more tracer materials has a total volume in the vessel of less than 1,000 cubic centimeters of fluid; and
injecting two or more tracer materials into the annulus of the well under pressure as part of a lift gas comprises releasing the tracer materials into a lift gas line by means of a high-pressure syringe or a surface pump.

20. The method of claim 1 , further comprising:
installing the fluid analyzer at a location remote from the production well, but at a location within a designated field to which the production well is assigned for production.

21. The method of claim 1 , further comprising:
installing the fluid analyzer at a location proximate the production well.

22. A method for evaluating annulus-tubing communication points in a production well, the production well having one or more strings of casing extending below a surface, and a string of production tubing within the strings of casing thereby forming an annulus, and the method comprising:
placing up to 1,000 cc's of each of two or more tracer materials into a portable vessel, wherein each of the tracer materials defines a material that is not native to formation fluids from the production well;
determining a rate of diffusivity of each of the tracer materials;
causing the one or more tracer materials to be injected from the vessel into the annulus of the well under pressure as part of a lift gas;
further injecting the lift gas in order to cause the two or more tracer materials to

Assignees

• Romer Michael C
• Long Ted A
• Hord Tony W
• Exxonmobil Upstream Res Co

Inventors

• Romer Michael C
• Long Ted A
• Hord Tony W

Classifications

• E21B43/168

  Injecting a gaseous medium · CPC title

• E21B43/14

  Obtaining from a multiple-zone well · CPC title

• G01M3/202

  using mass spectrometer detection systems · CPC title

• E21B41/0092

  Fixed Constructions · mapped topic

• E21B43/123

  Gas lift valves · CPC title