METHODS AND APPARATUS FOR DOWNHOLE CHARACTERIZATION OF EMULSION STABILITY

• US 20110083842A1
• Filed: 10/13/2009
• Published: 04/14/2011
• Est. Priority Date: 10/13/2009
• Status: Active Grant

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Hsu, Kai, Indo, Kentaro
• Granted Patent: US 8,146,655 B2
• Time in Patent Office: Days
• US Class Current: 166/250.01
• CPC Class Codes: E21B 49/0875 determining specific fluid parameters
• CPC Class Codes: E21B 49/10 using side-wall fluid samplers or testers
• CPC Class Codes: G01N 21/534 by measuring transmission alone, i.e. determining opacity
• CPC Class Codes: G01N 33/2823 raw oil, drilling fluid or polyphasic mixtures hydrocarbon content of earth materials G01N33/241; prospecting G01V; drilling per se E21B

Abstract

A method (and corresponding apparatus) for downhole fluid analysis of petroleum formation fluids. The method includes capturing in a chamber of a downhole tool at least two immiscible formation fluids in a generally segregated state (the fluids including petroleum), activating a fluid mixing means to mix the fluids in the chamber to create an emulsion therefrom, and allowing the emulsified fluids to segregate while measuring light transmittance through the segregating fluids in order to calculate a transition time period based on the light transmittance through the fluids in the chamber. The transition time period is preferably bounded by the time required for the light transmittance values measured by the light detector to reach a baseline light transmittance. The transition time period characterizes the stability of an emulsion formed by the captured fluids. The methods and apparatus can also be used for other fluid testing applications beyond downhole formation fluid testing.

Claims

1. A method for downhole analysis of petroleum formation fluids comprising:

(a) providing a chamber in a downhole tool suspended in a wellbore;

(b) capturing in the chamber at least two immiscible fluids in a generally segregated state, the at least two fluids including petroleum fluid;

(c) emulsifying the fluids in the chamber by activating a fluid mixing means for mixing the fluids;

(d) allowing the emulsified fluids to segregate by deactivating the mixing means;

(e) transmitting light into the fluids in the chamber and measuring light transmittance values through the fluids over time during (d); and

(f) calculating the duration of a transition time period based upon the light transmittance values measured in (e), the transition time period beginning at the time of deactivation of the fluid mixing means, and the transition time period ending at a time dictated by evaluation of a predetermined criterion associated with the light transmittance values measured in (e).

2. A method according to claim 1, further comprising:

(g) transmitting light into the fluids in the generally segregated state as captured in (b) and measuring light transmittance through the fluids to derive a baseline light transmittance; and

wherein the predetermined criterion of (f) is satisfied in the event that the light transmittance measured in (e) reaches the baseline light transmittance derived at step (g).

3. A method according to claim 2, wherein the baseline light transmittance is derived from light transmittance values measured during (g) with the mixing means deactivated.

4. A method according to claim 1, further comprising:

(g) calculating the rate of change of the light transmittance values measured in (e); and

wherein the predetermined criterion of (f) is satisfied in the event that the rate of change of the light transmittance values calculated in (g) decreases to a predetermined value.

5. A method according to claim 1, wherein the chamber comprises a circulating flow loop housed within the downhole tool, and the fluid mixer means mixes and circulates fluids in the circulating flow loop.

6. A method according to claim 1, further comprising:

(g) outputting or storing the transition time period duration calculated in (f) for characterizing emulsion stability for the fluids captured in (b).

7. A method according to claim 1, wherein the transmitting of light into the fluids and the measuring of light transmittance through the fluids during (e) is accomplished with a light source and light detector disposed on opposite sides of the chamber.

8. A method according to claim 1, further comprising inputting formation fluid into the chamber via a flowline fluidly coupled to a probe for drawing formation fluid into the flowline.

10. A method according to claim 1, wherein the transmitting of light into the fluids and the measuring of light transmittance through the fluids during (e) is accomplished with a light source and light detector disposed on the same side of the chamber.

9. A method for downhole analysis of petroleum formation fluids comprising:

(a) providing a chamber in a downhole tool suspended in a wellbore;

(b) capturing in the chamber at least two immiscible fluids in a generally segregated state, the at least two fluids including petroleum fluid;

(c) emulsifying the fluids in the chamber by activating a fluid mixing means for mixing the fluids;

(d) allowing the emulsified fluids to segregate by deactivating the mixing means;

(e) transmitting light into the fluids in the chamber and measuring backscattered light from the fluids over time during (d); and

(f) calculating the duration of a transition time period based upon the backscattered light values measured in (e), the transition time period beginning at the time of deactivation of the fluid mixing means, and the transition time period ending at a time dictated by evaluation of a predetermined criterion associated with the backscattered light values measured in (e).

11. An apparatus for downhole fluid testing of petroleum fluid, the apparatus comprising:

a housing positionable within a wellbore adjacent a formation containing petroleum fluid, the housing supporting a chamber, a probe, at least one valve, fluid mixing means, a light source, a light detector, and a control unit;

the probe for drawing at least two generally segregated fluids from the formation into the chamber, the two fluids including petroleum fluid;

the at least one valve for sealing the fluids in the chamber;

the fluid mixing means for mixing the fluids in the chamber into an emulsified state;

the light source for transmitting light into the fluids in the chamber;

the light detector for measuring the transmittance of light from the light source through the fluids in the chamber; and

the control unit operably coupled to the fluid mixing means and the light detector, the control unit adapted to deactivate the fluid mixing means in order to allow the emulsified fluids to segregate, and the control unit including means for measuring light transmittance values output by the light detector over time while the fluid mixing means is deactivated in order to calculate a transition time period for the fluids captured in the chamber, whereby the duration of the transition time period characterizes emulsion stability for the fluids captured in the chamber.

12. An apparatus according to claim 11, wherein the control unit comprises means for calculating the duration of the transition time period based upon the light transmittance values measured while the fluid mixing means is deactivated.

13. An apparatus according to claim 11, wherein the control unit communicates the light transmittance values to another data processing system that calculates duration of the transition time period based upon the light transmittance values communication from the control unit.

14. An apparatus according to claim 11, wherein:

the control unit outputs the light transmittance values to another data processing system for logging and analysis by a user; and

wherein the user calculates the duration of the transition time period based upon the light transmittance values output by the control unit.

15. An apparatus according to claim 11, wherein the transition time period begins at the time of deactivation of the fluid mixing means, and the transition time period ends at a time dictated by evaluation of a predetermined criterion associated with the light transmittance values output by the light detector.

16. An apparatus according to claim 15, wherein:

the control unit is adapted to measure light transmittance through the fluids captured in the chamber to derive a baseline light transmittance; and

the predetermined criterion that dictates the transition time period is satisfied in the event that the light transmittance measured while the fluid mixing means is deactivated to allow for segregation reaches the baseline light transmittance.

17. An apparatus according to claim 16, wherein the baseline light transmittance is derived from light transmittance values measured with the fluid mixing means deactivated.

18. An apparatus according to claim 15, wherein:

the control unit is adapted to measure light transmittance through the fluids captured in the chamber; and

the predetermined criterion that dictates the transition time period is satisfied in the event that the rate of change of the light transmittance decreases to a predetermined value.

19. An apparatus according to claim 11, wherein the chamber comprises a circulating flow loop, and the fluid mixer means mixes and circulates fluids in the circulating flow loop.

20. An apparatus according to claim 11, further comprising a pressurization assembly in fluid communication with the chamber and capable of changing the pressure of the fluids in the chamber.

21. An apparatus according to claim 20, wherein the control unit is operably coupled to the pressurization assembly for operation thereof.

22. An apparatus according to claim 11, further comprising a first sensing means for measuring at least one of temperature and pressure of fluids captured in the chamber.

23. An apparatus according to claim 22, further comprising a second sensing means for measuring density of fluids in the chamber.

24. An apparatus for downhole fluid testing of petroleum fluid, the apparatus comprising:

a housing positionable within a wellbore adjacent a formation containing petroleum fluid, the housing supporting a chamber, a probe, at least one valve, fluid mixing means, a light source, a light detector, and a control unit;

the probe for drawing at least two generally segregated fluids from the formation into the chamber, the two fluids including petroleum fluid;

the at least one valve for sealing the fluids in the chamber;

the fluid mixing means for mixing the fluids in the chamber into an emulsified state;

the light source for transmitting light into the fluids in the chamber;

the light detector for measuring the backscatter of light from the fluids in the chamber; and

the control unit operably coupled to the fluid mixing means and the light detector, the control unit adapted to deactivate the fluid mixing means in order to allow the emulsified fluids to segregate, and the control unit including means for measuring light backscatter values output by the light detector over time while the fluid mixing means is deactivated in order to calculate a transition time period for the fluids captured in the chamber, whereby the duration of the transition time period characterizes emulsion stability for the fluids captured in the chamber.

25. A fluid testing apparatus, comprising:

a chamber;

a probe for drawing at least two generally segregated immiscible fluids into the chamber;

at least one valve for sealing the fluids in the chamber;

fluid mixing means for mixing the fluids in the chamber into an emulsified state;

a light source for transmitting light into the fluids in the chamber;

a light detector for measuring transmittance of light from the light source through the fluids in the chamber; and

a control unit operably coupled to the fluid mixing means and the light detector, the control unit adapted to deactivate the fluid mixing means in order to allow the emulsified fluids to segregate, and the control unit including

means for measuring light transmittance values output by the light detector over time while the fluid mixing means is deactivated, and

means for calculating the duration of the transition time period based upon the light transmittance values measured while the fluid mixing means is deactivated.

26. A fluid testing apparatus according to claim 25, wherein the transition time period begins at the time of deactivation of the fluid mixing means, and the transition time period ends at a time dictated by evaluation of a predetermined criterion associated with the light transmittance values output by the light detector.

27. A fluid testing apparatus according to claim 26, wherein:

the control unit is adapted to measure light transmittance through the fluids captured in the chamber to derive a baseline light transmittance; and

the predetermined criterion that dictates the transition time period is satisfied in the event that the light transmittance measured while the fluid mixing means is deactivated to allow for segregation reaches the baseline light transmittance.

28. A fluid testing apparatus according to claim 27, wherein the baseline light transmittance is derived from light transmittance values measured with the fluid mixing means deactivated.

29. A fluid testing apparatus according to claim 26, wherein:

the control unit is adapted to measure light transmittance through the fluids captured in the chamber to derive the rate of change of the light transmittance; and

the predetermined criterion that dictates the transition time period is satisfied in the event that the rate of change of the light transmittance measured while the fluid mixing means is deactivated to allow for segregation decreases to a predetermined value.

30. A fluid testing apparatus according to claim 25, wherein the chamber comprises a circulating flow loop, and the fluid mixer means mixes and circulates fluids in the circulating flow loop.