FORMATION FLUID SAMPLING TOOLS AND METHODS UTILIZING CHEMICAL HEATING

• US 20110132609A1
• Filed: 01/07/2011
• Published: 06/09/2011
• Est. Priority Date: 09/18/2006
• Status: Active Grant

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Mullins, Oliver C., Hegeman, Peter S., Vasques, Ricardo, Ayan, Cosan, Goodwin, Anthony, Del Campo, Christopher Scott, Betancourt, Soraya S., Van Hal, Ronald E. G., Dubost, Francois Xavier, Raghuraman, Bhavani
• Granted Patent: US 8,283,174 B2
• Time in Patent Office: Days
• US Class Current: 166/300
• CPC Class Codes: E21B 36/008 using chemical heat generating means
• CPC Class Codes: E21B 49/10 using side-wall fluid samplers or testers

Abstract

A formation fluid sampling tool is provided with reactants which are carried downhole and which are combined in order to generate heat energy which is applied to the formation adjacent the borehole. By applying heat energy to the formation, the formation fluids are heated, thereby increasing mobility, and fluid sampling is expedited.

Claims

1. A method, comprising:

locating a tool containing at least two separated reactants in a subsurface formation;

injecting an injection fluid from the tool into the formation; and

using the reactants in an exothermic chemical reaction to heat injection fluid.

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

withdrawing into the tool at least some of the injection fluid and some formation hydrocarbon fluid from the formation.

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

mixing said separated reactants together while in said tool to generate said injection fluid which is heated by said exothermic chemical reaction, wherein said injecting comprises injecting heated fluid into the formation.

4. A method according to claim 3, wherein:

said heated fluid is at least 50°

C. warmer than an ambient temperature of the tool.

5. A method according to claim 3, wherein:

said heated fluid is at least 100°

C. warmer than an ambient temperature of the tool.

6. A method according to claim 3, wherein:

said heated fluid comprises steam or hot water.

7. A method according to claim 3, wherein:

said heated fluid comprises a hot acid.

8. A method according to claim 3, wherein:

said injecting comprises injecting the separated reactants separately into the formation or into a borehole adjacent the formation such that said exothermic chemical reaction occurs in the formation or in the borehole.

9. A method according to claim 1, wherein:

said reactants include water and a chemical which reacts with water in an exothermic dissolving reaction.

10. A method according to claim 9, wherein:

said chemical is a salt.

11. A method according to claim 10, wherein:

said salt is chosen from a group consisting of a magnesium salt, a potassium salt, an aluminum salt, and a sodium salt.

12. A method according to claim 10, wherein:

said salt is at least one magnesium chloride, magnesium sulfate, aluminum bromide, aluminum chloride, potassium hydroxide and sodium hydroxide.

13. A method according to claim 9, wherein:

said injection fluid comprises said water and said chemical which reacts with water in an exothermic dissolving reaction.

14. A method according to claim 9, wherein:

said chemical is a chemical which when reacted with water will generate an acid solution.

15. A method according to claim 14, wherein:

said chemical which when reacted with water will generate at least one acid is chosen from phosphorous trichloride, phosphorous pentoxide, phosphorous pentachloride, and sulfur trioxide.

16. A method according to claim 14, wherein:

said injection fluid comprises said acid solution.

17. A method according to claim 1, wherein:

said reactants include an acid and a base.

18. A method according to claim 17, wherein:

said acid is chosen from HCl and HNO₃, and said base is NAOH.

19. A method according to claim 17, wherein:

said injection fluid comprises a solution of said acid and said base.

20. A method according to claim 1, wherein:

said reactants include an acid and water.

21. A method according to claim 20, wherein:

said acid is chosen from hydrochloric acid, sulfuric acid and pyro-phosphorous acid.

22. A method according to claim 20, wherein:

said injection fluid comprises said acid diluted by said water.

23. A method according to claim 1, wherein:

said reactants include water, a chemical which when reacted with water will generate an acid solution, and a base.

24. A method according to claim 1, wherein:

said reactants include chemicals which will undergo an exothermic reduction-oxidation reaction when brought into contact with each other.

25. A method according to claim 1, wherein:

said injecting an injection fluid comprises varying a rate of injection while injecting.

26. A method according to claim 1, wherein:

said injecting an injection fluid comprises injecting a first amount of said injection fluid, stopping said injection, and then injecting a second amount of said injection fluid.

27. A method according to claim 26, wherein:

said second amount is different than said first amount.

28. A method according to claim 26, wherein:

said first amount of said injection fluid is injected at a first rate, and said second amount of said injection fluid is injected at a second rate different than said first rate.

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

disposing said injection fluid withdrawn into the tool.

30. A method according to claim 29, further comprising:

storing a substantially pure sample of said formation hydrocarbon fluid withdrawn into the tool, and bringing said substantially pure sample uphole.

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

temporarily storing at least some of said injection fluid withdrawn into the tool, and

reinjecting the injection fluid withdrawn into the tool back into the formation.

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

monitoring at least one parameter of fluid withdrawn into the tool.

33. A method according to claim 31, wherein:

said at least one parameter includes at least one of temperature, viscosity, optical density, and flow-rate.

34. A method according to claim 32, further comprising:

determining an indication of a parameter of said formation from said at least one parameter of said fluid.

35. A method according to claim 2, wherein:

said injecting is accomplished through a first port of said tool, and said withdrawing is accomplished through a second port of said tool.

36. A method according to claim 2, wherein:

said injecting and said withdrawing are accomplished through a single port of said tool.

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

applying electrical or electro-magnetic energy to said formation at a site where said injection fluid is injected.

38. A method according to claim 37, further comprising:

withdrawing into the tool at least some of the injection fluid and some formation hydrocarbon fluid from the formation, wherein

said energy is applied during said withdrawing.

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

prior to injecting, drilling a hole in a casing in a borehole of the formation, wherein said injecting is accomplished through said hole.