Monitoring of downhole parameters and tools utilizing fiber optics

• US 6,281,489 B1
• Filed: 05/01/1998
• Issued: 08/28/2001
• Est. Priority Date: 05/02/1997
• Status: Expired due to Term

• Current Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Original Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Inventors: Johnson, Michael H., Leggett, Nigel, Tubel, Paulo S., Lembcke, Jeffrey J., Hickey, Kurt A., Harrell, John W., Williams, Glynn
• Primary Examiner(s): Lee, John R.
• Application Number:
  US09/071,764
• Time in Patent Office: 1,215 Days
• Field of Search: 250/227.11, 250/227.14, 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, 166/270.01, 356/432, 356/436
• 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. An apparatus for controlling chemical injection of a chemical from a surface treatment system for an oilfield well, comprising:

(a) a chemical injection device injecting one or more chemicals into the treatment system for the treatment of fluids produced from the oilfield well;

(b) at least one chemical sensor associated with the treatment system for sensing at least one parameter of the injected chemical or for sensing at least one chemical property of the fluids produced from the oilfield well; and

(c) a control and monitoring system for controlling the chemical injection device in response, at least in part, to information from said at least one chemical sensor.

2. The apparatus of claim 1 further comprising at least one additional sensor distributed in said treatment system for measuring at least one of pressure, temperature and flow, said distributed sensors communicating with said control and monitoring system.

3. The apparatus of claim 2 wherein said at least one chemical sensor comprises at least one fiber optic sensor disposed downhole in the oilfield well.

4. The apparatus of claim 3 wherein said at least one fiber optic includes a probe which is sensitive to at least one selected chemically related parameter.

5. The apparatus of claim 4 wherein said probe includes a sol gel sensor.

6. The apparatus of claim 1 wherein said control and monitoring system includes a computerized controller.

7. The apparatus of claim 1 wherein said at least one chemical sensor is a fiber optic sensor.

8. The apparatus of claim 1 wherein the at least one chemical sensor senses at least one chemical property of the fluids produced from the oilfeld well, said at least one chemical property selected from the group consisting of:

(i) potential ionic content, (ii) the covalent content, (iii) pH level, (iv) oxygen levels, (v) organic precipitates, (vi) paraffin content, (vii) H₂S content, and (viii) scale buildup.

9. The apparatus of claim 1 wherein said one or more chemicals are selected from the group consisting of:

(i) long chain amines, (ii) aminidiazolines, and, (iii) CronoxÔ

™

.

10. The apparatus of claim 1 wherein the one or more chemicals are selected from the group consisting of:

(i) a corrosion inhibitor, and, (ii) a de-emulsifier.

11. A method of monitoring chemical injection into a surface treatment system of an oilfield well, comprising:

(a) injecting one or more chemicals into the treatment system for the treatment of fluids produced in the oilfield well;

(b) using at least one chemical sensor associated with the treatment system for sensing at least one chemical property of the fluids in the treatment system; and

(c) altering injection of said one or more chemicals in response to an output of said at least one chemical sensor.

12. The method of claim 11 wherein said chemical sensor is a fiber optic sensor.

13. The method of claim 12 wherein said fiber optic chemical sensor includes a probe which is sensitive to at least one selected chemically related parameter.

14. The method of claim 13 wherein said probe includes a sol gel sensor.

15. The method of claim 11 wherein using said at least one chemical sensor further comprises sensing at least one chemical property of the produced fluid selected from the group consisting of:

(i) potential ionic content, (ii) the covalent content, (iii) pH level, (iv) oxygen levels, (v) organic precipitates, (vi) paraffin content, (vii) H₂S content, and (viii) scale buildup.

16. The method of claim 11 wherein injecting one or more chemicals further comprises injecting a chemical selected from the group consisting of:

(i) long chain amines, (ii) aminidiazolines, and, (iii) CronoxÔ

™

.

17. The method of claim 11 wherein injecting one or more chemicals further comprises injecting a chemical selected from the group consisting of:

(i) a corrosion inhibitor, and, (ii) a de-emulsifier.