Wellbores utilizing fiber optic-based sensors and operating devices

• US 6,531,694 B2
• Filed: 02/06/2001
• Issued: 03/11/2003
• Est. Priority Date: 05/02/1997
• Status: Expired due to Term

• Current Assignee: Sensor Highway Limited (Schlumberger NV)
• Original Assignee: Sensor Highway Limited (Schlumberger NV)
• Inventors: Hickey, Kurt A., Johnson, Michael H., Leggett, Nigel, Tubel, Paulo S., Lembcke, Jeffrey J., Harrell, John W., Williams, Glynn
• Primary Examiner(s): Allen, Stephone B.
• Application Number:
  US09/778,696
• Publication Number:
  US 20010020675A1
• Time in Patent Office: 763 Days
• Field of Search: 250/227.11, 250/227.14, 250/227.21, 250/227.24, 250/227.27, 250/256, 385/141, 385/142, 385/143, 385/144, 385/145, 385/12, 385/13, 166/250.01, 166/251.1, 166/254.2, 166/250.15, 166/270.1, 356/432, 356/436, 359/142, 359/143, 359/144
• US Class Current: 250/227.14
• CPC Class Codes: E21B 33/1275 inflated by down-hole pumping means operated by a down-hole drive
• CPC Class Codes: E21B 37/06 using chemical means for preventing or limiting , e.g. eliminating, the deposition of paraffins or like substances
• CPC Class Codes: E21B 41/0035 Apparatus or methods for multilateral well technology, e.g. for the completion of or workover on wells with one or more lateral branches
• CPC Class Codes: E21B 41/02 in situ inhibition of corrosion in boreholes or wells
• CPC Class Codes: E21B 43/12 Methods or apparatus for controlling the flow of the obtained fluid to or in wells E21B43/25 takes precedence; valve arrangements E21B34/00
• CPC Class Codes: E21B 43/16 Enhanced recovery methods for obtaining hydrocarbons
• CPC Class Codes: E21B 43/20 Displacing by water
• CPC Class Codes: E21B 43/25 Methods for stimulating production by vibrating earth formations E21B43/003
• CPC Class Codes: E21B 47/006 Detection of corrosion or deposition of substances
• CPC Class Codes: E21B 47/017 Protecting measuring instruments
• CPC Class Codes: E21B 47/06 Measuring temperature or pressure
• CPC Class Codes: E21B 47/07 Temperature
• CPC Class Codes: E21B 47/107 using acoustic means
• CPC Class Codes: E21B 47/11 using tracers; using radioactivity
• CPC Class Codes: E21B 47/114 using light radiation
• CPC Class Codes: E21B 47/135 using light waves, e.g. infrared or ultraviolet waves
• CPC Class Codes: E21B 49/00 Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
• CPC Class Codes: E21B 49/006 Measuring wall stresses in the borehole
• CPC Class Codes: E21B 49/008 by injection test; by analysing pressure variations in an injection or production test, e.g. for estimating the skin factor measuring pressure E21B47/06
• CPC Class Codes: E21B 49/08 Obtaining fluid samples or testing fluids, in boreholes or wells
• CPC Class Codes: G01D 5/268 : using optical fibres G01D5/28 - G01D5/38 take precedence
• CPC Class Codes: G01N 21/31 : Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry G01N21/72 takes precedence
• CPC Class Codes: G01V 1/40 : specially adapted for well-logging
• CPC Class Codes: G01V 1/42 : using generators in one well and receivers elsewhere or vice versa G01V1/52 takes precedence
• CPC Class Codes: G01V 1/46 : Data acquisition
• CPC Class Codes: G01V 1/52 : Structural details
• CPC Class Codes: G01V 11/002 : Details, e.g. power supply systems for logging instruments, transmitting or recording data, specially adapted for well logging, also if the prospecting method is irrelevant means for transmitting well survey signals E21B47/12; signal transmission systems in general G08C; transmission in general H04B
• CPC Class Codes: G01V 7/08 : using balances
• CPC Class Codes: G01V 7/16 : specially adapted for use on moving platforms, e.g. ship, aircraft
• CPC Class Codes: G01V 8/02 : Prospecting

Abstract

This invention provides a method for controlling production operations using fiber optic devices. An optical fiber carrying fiber-optic sensors is deployed downhole to provide information about downhole conditions. Parameters related to the chemicals being used for surface treatments are measured in real time and on-line, and these measured parameters are used to control the dosage of chemicals into the surface treatment system. The information is also used to control downhole devices that may be a packer, choke, sliding sleeve, perforating device, flow control valve, completion device, an anchor or any other device. Provision is also made for control of secondary recovery operations online using the downhole sensors to monitor the reservoir conditions. The present invention also provides a method of generating motive power in a wellbore utilizing optical energy. This can be done directly or indirectly, e.g., by first producing electrical energy that is then converted to another form of energy.

Claims

1. A light actuated system for use in a wellbore, comprising:

(a) a light actuated transducer in the wellbore, said light actuated transducer adapted to transform a physical state of a component thereof upon application of optical energy;

(b) an optical waveguide conveying the optical energy from a source thereof to the light actuated transducer; and

(c) a control device in the wellbore operated at least in part by said change in the physical state of the component of the light actuated transducer to control an end use device in the wellbore.

2. The light actuated system of claim 1, wherein said transformation of the physical state is selected from the set consisting of (i) mechanical motion of the component, and (ii) a change in the physical properties of the component.

3. The light actuated system of claim 1 wherein the optical waveguide is one of (i) an optical fiber, and (ii) a fluid-filled waveguide.

4. The light actuated system of claim 1 wherein the transformation of the physical state includes the conversion of the optical energy to motion of a piezoelectric materal.

5. The light actuated system of claim 1 further comprising a plurality of fiber optic sensors for making distributed measurements.

6. The light actuated system of claim 1 further comprising a processor adapted to provide signals responsive to downhole parameters for controlling a downhole device.

7. The light actuated system of claim 1 wherein transformation of the physical state generates rotary power.

8. The light actuated system of claim 1 wherein the control device is one of (i) a fluid control device, (ii) an electronic power generation device, (iii) an electrical switching device, (iv) a fluid pressuring device, (v) a downhole light source, and (vi) an energy sensitive material that changes physical properties.

9. The light actuated system of claim 8 the end use device is selected from the group consisting of (i) flow control equipment, (ii) lifting equipment, (iii) injection equipment, (iv) perforating equipment, (v) packer, (vi) fluid separating equipment, (vii) sensing equipment, (viii) pump, and (ix) fluid treatment.

10. The light actuated system of claim 1 wherein transformation of the physical state includes the movement of a fluid and the source of the fluid is one of (i) a pressurized fluid supplied from a surface location, (ii) pressurized fluid supplied from the surface via a conduit carrying the optical waveguide to the light actuated system, and (iii) wellbore fluid at hydrostatic pressure.

11. The light actuated system of claim 10, further comprising a chamber containing the fluid, the chamber having a reciprocating piston therein, said piston reciprocating due to the expansion of the fluid upon application of optical energy.

12. The light actuated system of claim 1, wherein the transformation of the physical state comprises moving the component upon application of optical energy.

13. The light actuated system of claim 12, wherein transducer comprises a photovoltaic cell, said photovoltaic cell receiving the optical energy and converting it to electric current, said component receiving the electric current and moving as a result thereof.

14. The light actuated system of claim 1 further comprising at least one sensor in the wellbore providing measurements of at least one selected downhole parameter.

15. The light actuated system of claim 14 wherein the downhole parameter is one of (a) temperature, (b) pressure, (c) vibration, (d) acoustic filed, and (e) corrosion.

16. The light actuated system of claim 14 wherein the at least one sensor comprises a plurality of spaced apart sensors.

17. The light actuated system of claim 1, wherein the transformation of the physical state includes the expansion of a fluid.

18. The method of claim 17, further comprising a chamber containing the fluid, the chamber having a reciprocating piston therein, said piston reciprocating due to the expansion of the fluid upon application of optical energy.

19. The light actuated system of claim 18, wherein said reciprocating piston is reciprocated to pump a fluid.

20. The light actuated system of claim 19, further comprising a plurality of said reciprocating pistons and at least two of said plurality of reciprocating pistons being in fluid communication with each other.

21. The light actuated system of claim 18, wherein the chamber further has a plurality of reciprocating pistons that are reciprocated to generate rotary power.

22. The light actuated system of claim 21, wherein optical energy is supplied to said reciprocating pistons in a particular order with a predetermined phase difference.

23. The light actuated system of claim 21, wherein each of said reciprocating pistons includes an arm and each of said arms is coupled to a cam shaft that rotates to provide rotary power.

24. A method for producing formation fluids through a wellbore, comprising:

(a) providing a light actuated transducer in the wellbore, said light actuated transducer adapted to transform a physical state of a component thereof upon application of optical energy;

(b) providing a control device in the wellbore that is operated at least in part by said change in the physical state of the component of the light actuated transducer; and

(c) supplying optical energy to the light actuated transducer, causing said light actuated transducer to change the physical state of the component thereof, thereby operating the control device.

25. The method of claim 24 wherein causing said light actuated transducer to change the physical state of the component thereof further comprises a process selected from (i) moving the component, and, (ii) changing a physical property of the component.

26. The method of claim 24 further comprising providing a conduit supplying fluid under pressure to a device in the wellbore.

27. The method of claim 24 wherein the control device is one of (i) a fluid control device, (ii) an electronic power generation device, (iii) an electrical switching device, (iv) a fluid pressuring device, (v) a downhole light source, and (vi) an energy sensitive material that changes physical properties.

28. The method of claim 24 wherein causing said light actuated transducer to change the physical state of the component thereof further comprises at least one:

(i) controlling fluid flow using a fluid control device, (ii) generating electronic power, (iii) switching an electrical switching device, (iv) increasing pressure of a fluid using a pressuring device, (v) generating light using a downhole light source, and (vi) changing physical properties of an energy sensitive material.

29. The method of claim 24 further comprising using an end use device controlled at least in part by the control device, said end use device being one of (i) flow control equipment, (ii) lifting equipment, (iii) injection equipment, (iv) perforating equipment, (v)packer, (vi) fluid separating equipment, (vii) sensing equipment, (viii) pump, and (ix) fluid treatment equipment.

30. The method of claim 24 wherein the transformation of the physical state includes the conversion of the optical energy to motion of a piezoelectric material carrying the electrical energy.

31. The method of claim 24, further comprising converting the optical energy into an electric current, passing the electric current through the component, and generating movement in the component as a result of the passing step.

32. The method of claim 24 wherein supplying optical energy to the light actuated transducer further comprises using an optical waveguide selected from (i) an optical fiber, and (ii) a fluid-filled waveguide.

33. The method of claim 32 further comprising providing a conduit carrying the optical waveguide from the surface to the light actuated transducer.

34. The method of claim 24 wherein transformation of the physical state includes the movement of a fluid and the source of the fluid is one of (i) a pressurized fluid supplied from a surface location, (ii) pressurized fluid supplied from the surface via a conduit carrying the optical waveguide to the light actuated system, and (iii) wellbore fluid at hydrostatic pressure.

35. The method of claim 34 further comprising using an end use device controlled at least in part by the control device, said end use device being one of (i) flow control equipment, (ii) lifting equipment, (iii) injection equipment, (iv) perforating equipment, (v) packer, (vi) fluid separating equipment, (vii) sensing equipment, (viii) pump, and (ix) fluid treatment equipment.

36. The method of claim 24 further comprising using at least one sensor in the wellbore for providing measurements of at least one selected downhole parameter.

37. The method of claim 36 wherein the downhole parameter is one of (a) temperature, (b) pressure, (c) vibration, (d) acoustic field, and (e) corrosion.

38. The method of claim 36 further comprising a using a plurality of fiber optic sensors for making distributed measurements of a selected downhole parameter.

39. The method of claim 24, wherein transforming the physical state comprises expanding a fluid upon application of optical energy.

40. The method of claim 39, further comprising reciprocating a piston due to the expansion of the fluid upon application of optical energy.

41. The method of claim 40, further comprising pumping a fluid as a result of the reciprocating step.

42. The method of claim 40, further comprising reciprocating a plurality of said pistons to generate rotary power.

43. The method of claim 42, further comprising supplying optical energy to said reciprocating pistons in a particular order with a predetermined phase difference.

44. The method of claim 43, further comprising generating rotary power as a result of the supplying step.