Wellbores utilizing fiber optic-based sensors and operating devices

• US 6,787,758 B2
• Filed: 04/12/2002
• Issued: 09/07/2004
• Est. Priority Date: 02/06/2001
• Status: Expired due to Term

• Current Assignee: Sensor Highway Limited (SLB)
• Original Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Inventors: Johnson, Michael H., Tubel, Paulo S., Lembcke, Jeffrey J., Hickey, Kurt A., Harrell, John W., Leggett, Nigel, Williams, Glynn
• Primary Examiner(s): Allen, Stephone B.
• Application Number:
  US10/121,375
• Publication Number:
  US 20020109080A1
• Time in Patent Office: 879 Days
• Field of Search: 250/227.14, 250/253, 250/256, 166/316, 166/319, 166/374, 166/66.6, 166/66.7, 166/305.1, 166/320, 166/332.1, 166/334.4, 166/373, 166/53, 166/54, 181/108-110, 181/112, 181/122, 731/514.6, 731/520.1, 73/290.1, 356/301, 356/326, 367/81, 219/502
• 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 43/25 Methods for stimulating production by vibrating earth formations E21B43/003
• 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 49/08 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 1/226 Optoseismic systems
• 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

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 downhole equipment in a wellbore, comprising:

(a) a hydraulic line extending into the wellbore for supplying fluid under pressure downhole carried on a tubing in the wellbore;

(b) a plurality of fiber optic sensors providing measurements of a downhole parameter along the tubing in the wellbore;

(c) a hydraulically-controlled device on the tubing in the wellbore and in fluid communication with the hydraulic line, wherein said hydraulic line provides control of the hydraulically-operated device.

2. The apparatus of claim 1 wherein the plurality of sensors include at least one of (I) a temperature sensor, (ii) a pressure sensor, (iii) an acoustic sensor, (iv) a flow measurement sensor, and (v) a vibration sensor.

3. The apparatus of claim 1 further comprising a spectrometer in communication with at least one of said fiber optic sensors.

4. A method for monitoring a downhole parameter in a wellbore and controlling a hydraulically-operated device, comprising:

(a) providing a hydraulically operated device in the wellbore;

(b) conveying a hydraulic line in the wellbore, said hydraulic line supplying fluid under pressure to the hydraulically-operated device for controlling the operation of the hydraulically-operated device;

(c) providing a fiber optic sensor in the hydraulic line for measuring a downhole parameter along the hydraulic line so that the same hydraulic line provides measurement for the downhole parameter and the control of the hydraulically-operated device.

5. The method of claim 4 wherein the hydraulically-operated device is selected from a group consisting of (i) a flow control device, (ii) a packer, (iii) a choke, (iv) a perforating device, (v) an anchor, (vi) a completion device, and (vii) a production device.

6. A method of monitoring a downhole parameter in a wellbore and controlling a hydraulically-operated device, comprising:

(a) providing a hydraulically-operated device in the wellbore;

(b) conveying a hydraulic line in the wellbore, said hydraulic line supplying fluid under pressure to the hydraulically-operated device for controlling the operation of the hydraulically-operated device;

(c) providing a fiber optic senior in the hydraulic line for measuring a downhole parameter along the hydraulic line so that the same hydraulic line provides measurement for the downhole parameter and the control of the hydraulically-operated device;

wherein the downhole parameter is one of (i) temperature, (ii) pressure, (iii) vibration, (iv) acoustic measurement, (v) fluid flow, and (vi) a fluid property.

7. A method of monitoring a downhole parameter in a wellbore and controlling a hydraulically-operated device, comprising:

(a) providing a hydraulically-operated device in the wellbore;

(b) conveying a hydraulic line in the wellbore, said hydraulic line supplying fluid under pressure to the hydraulically-operated device for controlling the operation of the hydraulically-operated device;

(c) providing a fiber optic sensor in the hydraulic line for measuring a downhole parameter along the hydraulic line so that the hydraulic line provides measurement for to downhole parameter and the control of the hydraulically-operated device,

wherein the fiber optic sensor is selected from the set consisting of (i) a temperature sensor, (ii) a pressure sensor, (iii) an acoustic sensor, (iv) a flow measurement sensor, and (v) a vibration sensor.