CA2588059A1 - Identification of the channel frequency response using chirps and stepped frequencies - Google Patents
Identification of the channel frequency response using chirps and stepped frequencies Download PDFInfo
- Publication number
- CA2588059A1 CA2588059A1 CA002588059A CA2588059A CA2588059A1 CA 2588059 A1 CA2588059 A1 CA 2588059A1 CA 002588059 A CA002588059 A CA 002588059A CA 2588059 A CA2588059 A CA 2588059A CA 2588059 A1 CA2588059 A1 CA 2588059A1
- Authority
- CA
- Canada
- Prior art keywords
- signal
- location
- characteristic
- mechanical
- downhole
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
- 230000004044 response Effects 0.000 title claims 3
- 238000004891 communication Methods 0.000 claims abstract 15
- 238000012546 transfer Methods 0.000 claims abstract 4
- 238000000034 method Methods 0.000 claims 20
- 230000015572 biosynthetic process Effects 0.000 claims 12
- 238000001914 filtration Methods 0.000 claims 5
- 238000001228 spectrum Methods 0.000 claims 4
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims 4
- 239000012530 fluid Substances 0.000 claims 3
- 238000012545 processing Methods 0.000 claims 3
- 230000001902 propagating effect Effects 0.000 claims 3
- 230000004075 alteration Effects 0.000 claims 2
- 238000005553 drilling Methods 0.000 claims 2
- 230000006870 function Effects 0.000 claims 2
- 230000009977 dual effect Effects 0.000 claims 1
- 238000005259 measurement Methods 0.000 claims 1
- 230000003287 optical effect Effects 0.000 claims 1
- 238000010183 spectrum analysis Methods 0.000 abstract 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
- E21B47/14—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
- E21B47/18—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid, e.g. mud pressure pulse telemetry
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01H—MEASUREMENT OF MECHANICAL VIBRATIONS OR ULTRASONIC, SONIC OR INFRASONIC WAVES
- G01H15/00—Measuring mechanical or acoustic impedance
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01H—MEASUREMENT OF MECHANICAL VIBRATIONS OR ULTRASONIC, SONIC OR INFRASONIC WAVES
- G01H17/00—Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves, not provided for in the preceding groups
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
- G01V1/003—Seismic data acquisition in general, e.g. survey design
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V11/00—Prospecting or detecting by methods combining techniques covered by two or more of main groups G01V1/00 - G01V9/00
- G01V11/002—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
-
- G—PHYSICS
- G08—SIGNALLING
- G08C—TRANSMISSION SYSTEMS FOR MEASURED VALUES, CONTROL OR SIMILAR SIGNALS
- G08C23/00—Non-electrical signal transmission systems, e.g. optical systems
Landscapes
- Physics & Mathematics (AREA)
- Engineering & Computer Science (AREA)
- Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- General Physics & Mathematics (AREA)
- Mining & Mineral Resources (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geophysics (AREA)
- Remote Sensing (AREA)
- Acoustics & Sound (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Geochemistry & Mineralogy (AREA)
- Radar Systems Or Details Thereof (AREA)
- Geophysics And Detection Of Objects (AREA)
- Arrangements For Transmission Of Measured Signals (AREA)
- Radio Relay Systems (AREA)
- Ultra Sonic Daignosis Equipment (AREA)
- Measurement Of Velocity Or Position Using Acoustic Or Ultrasonic Waves (AREA)
- Synchronisation In Digital Transmission Systems (AREA)
Abstract
The transfer function of the communication channel in a mud pulse telemetry system is determined by sending a known signal through the channel and spectral analysis of the received signal. The known signal may be a chirp signal or a stepped frequency signal. Based on the determined transfer function, operating parameters of the pulser are adjusted.
Claims (40)
1. A method of communicating signals in a wellbore between a surface location and a downhole location, the method comprising:
(a) generating a mechanical signal at one of the surface location and downhole location, (b) receiving a signal indicative of the generated mechanical signal at the other of the surface and downhole locations; and (c) estimating from the received signal and the generated mechanical signal a characteristic of a communication channel between the surface and downhole locations.
(a) generating a mechanical signal at one of the surface location and downhole location, (b) receiving a signal indicative of the generated mechanical signal at the other of the surface and downhole locations; and (c) estimating from the received signal and the generated mechanical signal a characteristic of a communication channel between the surface and downhole locations.
2. The method of claim 1 wherein the generated mechanical signal is at least one of: (i) an alteration of a fluid flow, and, (ii) a pressure pulse.
3. The method of claim 1 wherein the received signal comprises a measurement of at least one of: (i) a pressure , and (ii) a fluid flow .
4. The method of claim 1 wherein the generated mechanical signal is selected from the group consisting of (i) a stepped frequency signal, (ii) a linear chirp signal, (iii) a nonlinear chirp signal, and (iv) a pseudo-random sequence, (iii) a pseudo-random binary sequence.
5. The method of claim 1 wherein the generated mechanical signal is generated at the downhole location during a pause in drilling operations.
6. The method of claim 1 wherein the communication channel comprises a mud flow path.
7. The method of claim 1 wherein the characteristic of the communication channel comprises a transfer function.
8. The method of claim 1 wherein estimating the characteristic further comprises at least one of (i) cross-correlating the received signal with the generated mechanical signal, (ii) using a frequency spectrum of the received signal, and, (iii) using a frequency spectrum of the generated mechanical signal.
9. The method of claim 1 further comprising: using the determined characteristic for selecting an operating frequency for communication of at least one of (i) instructions from the surface location to the downhole location, and, (ii) data from the downhole location to the surface location.
10. The method of claim 1 wherein the mechanical signal further comprises a chirp signal, and wherein estimating the characteristic comprises applying a chirp transform to the received signal
11. The method of claim 10 wherein applying the chirp transform further comprises a low pass filtering based at least in part on a chirp rate of the mechanical signal and a maximum delay in the channel.
12. A system for communicating signals in a wellbore between a surface location and a downhole location, the system comprising:
(a) a mechanical source which generates a mechanical signal at one of the surface location and downhole location, (b) a receiver which receives a signal indicative of the generated mechanical signal at the other of the surface and downhole locations;
and (c) a processor which determines from the received signal and the generated mechanical signal a characteristic of a communication channel between the surface and downhole locations.
(a) a mechanical source which generates a mechanical signal at one of the surface location and downhole location, (b) a receiver which receives a signal indicative of the generated mechanical signal at the other of the surface and downhole locations;
and (c) a processor which determines from the received signal and the generated mechanical signal a characteristic of a communication channel between the surface and downhole locations.
13. The system of claim 12 wherein the mechanical source comprises a pulser including an oscillating shear valve.
14. The system of claim 12 wherein generated mechanical signal further comprises at least one of: (i) an alteration of a fluid flow, and, (ii) a pressure pulse.
15. The system of claim 12 wherein the receiver is selected from the group consisting of (i) a hydrophone, (ii) a pressure transducer, (iii) a dual pressure transducer, and (iv) a flow meter.
16. The system of claim 12 wlierein the generated mechanical signal is selected from the group consisting of (i) a stepped frequency signal, and (ii) a linear chirp signal, (iii) a nonlinear chirp signal, (iv) a pseudo-random sequence, and (v) a pseudo random binary sequence.
17. The system of claim 12 wherein the source of the mechanical signal is downhole and the mechanical signal is generated during a pause in drilling operations at the downhole location.
18. The system of claim 12 wherein the communication channel comprises a mud flow path.
19. The system of claim 12 wherein the characteristic of the communication channel comprises a transfer function.
20. The system of claim 12 wherein processor determines the characteristic by at least one of : (i) cross-correlating the received mechanical signal with the generated signal, (ii) determining a frequency spectrum of the received signal, and (iii) determining a frequency spectrum of the generated mechanical signal.
21. The system of claim 12 wherein the processor further uses the determined characteristic for selecting an operating frequency for communication of at least one of (i) instructions from the surface location to the downhole location, and (ii) data from the downhole location to the surface location.
22. The system of claim 12 wherein the processor is at the downhole location.
23. The system of claim 12 wherein the mechanical source is part of a bottomhole assembly (BHA).
24. The system of claim 12 wherein the generated mechanical signal comprises a chirp signal, and wherein the processor determines the characteristic of the communication channel by applying a chirp transform.
25. A computer readable medium for use with a system for communicating signals in a wellbore between a surface location and a downhole location, the system comprising:
(a) a mechanical source which generates a mechanical signal at one of the surface location and downhole location, (b) a receiver which receives a signal indicative of the generated mechanical signal at the other of the surface and downhole locations;
the medium further comprising instructions which enable a processor to estimate from the received signal and the generated mechanical signal a characteristic of the communication channel between the surface and downhole locations.
(a) a mechanical source which generates a mechanical signal at one of the surface location and downhole location, (b) a receiver which receives a signal indicative of the generated mechanical signal at the other of the surface and downhole locations;
the medium further comprising instructions which enable a processor to estimate from the received signal and the generated mechanical signal a characteristic of the communication channel between the surface and downhole locations.
26. The computer readable medium of claim 25 further comprising at least one of (i) a ROM, (iI) an EPROM, (iii) an EAROM, (iv) a flash memory, and (v) an optical disk.
27. A method of determining a characteristic of a communication channel associated with an earth formation, the method comprising:
(a) using a mechanical device for generating a swept frequency signal which propagates in the channel, the propagating signal including a harmonic distortion;
(b) receiving the propagating signal at at least one receiver to produce a received signal responsive to the characteristic of the channel;
(c) processing the received signal to estimate the characteristic of the channel, the processing including the use of a chirp transform.
(a) using a mechanical device for generating a swept frequency signal which propagates in the channel, the propagating signal including a harmonic distortion;
(b) receiving the propagating signal at at least one receiver to produce a received signal responsive to the characteristic of the channel;
(c) processing the received signal to estimate the characteristic of the channel, the processing including the use of a chirp transform.
28. The method of claim 27 wherein the communication channel further comprises a borehole in the earth formation.
29. The method of claim 27 wherein the characteristic further comprises an impulse response of the channel.
30. The method of claim 27 further comprising positioning the mechanical device at a location selected from (i) a surface location, (ii) within a body of water, (iii) within a borehole in the earth formation, (iv) on a bottomhole assembly conveyed in a borehole in the earth formation.
31. The method of claim 27 further comprising positioning the at least one receiver at a location selected from (i) a surface location, (ii)within a body of water, (iii) within a borehole in the earth formation, and (iv) on a bottomhole assembly conveyed in a borehole in the earth formation..
32. The method of claim 27 wherein the chirp transform further comprises:
(i) a correlation with a conjugate of the swept frequency signal;
(ii) a low pass filtering; and (iii) a correlation with the swept frequency signal.
(i) a correlation with a conjugate of the swept frequency signal;
(ii) a low pass filtering; and (iii) a correlation with the swept frequency signal.
33. The method of claim 32 further comprising selecting a parameter of the low pass filtering based at least in part on a chirp rate of the swept frequency signal and a maximum delay in the channel.
34. A system for determining a characteristic of a communication channel associated with an earth formation, the system comprising:
(a) a mechanical device which generates a swept frequency signal which propagates in the channel, the propagating signal including a harmonic;
(b) a receiver which produces a received signal responsive to the characteristic of the channel;
(c) a processor which estimates the characteristic of the channel from the received signal using a processing which includes the use of a chirp transform.
(a) a mechanical device which generates a swept frequency signal which propagates in the channel, the propagating signal including a harmonic;
(b) a receiver which produces a received signal responsive to the characteristic of the channel;
(c) a processor which estimates the characteristic of the channel from the received signal using a processing which includes the use of a chirp transform.
35. The system of claim 34 wherein the communication channel further comprises a borehole in the earth formation.
36. The system of claim 34 wherein the characteristic further comprises an impulse response of the channel.
37. The system of claim 34 wherein the mechanical device is positioned at a location selected from (i) a surface location, (ii) within a body of water, (iii) within a borehole in the earth formation, (iv) on a bottomhole assembly conveyed in a borehole in the earth formation.
38. The system of claim 34 wherein the at least one receiver is positioned at a location selected from (i) a surface location, (ii)within a body of water, (iii) within a borehole in the earth formation, and (iv) on a bottomhole assembly conveyed in a borehole in the earth formation.
39. The system of claim 36 wherein the processor applies the chirp transform by further performing:
(i) a correlation with a conjugate of the swept frequency signal;
(ii) a low pass filtering; and (iii) a correlation with the swept frequency signal.
(i) a correlation with a conjugate of the swept frequency signal;
(ii) a low pass filtering; and (iii) a correlation with the swept frequency signal.
40. The system of claim 39 wherein the processor selects a parameter of the low pass filtering based at least in part on a chirp rate of the swept frequency signal and a maximum delay in the channel.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US62999004P | 2004-11-22 | 2004-11-22 | |
| US60/629,990 | 2004-11-22 | ||
| PCT/US2005/042329 WO2006058006A2 (en) | 2004-11-22 | 2005-11-19 | Identification of the channel frequency response using chirps and stepped frequencies |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2588059A1 true CA2588059A1 (en) | 2006-06-01 |
| CA2588059C CA2588059C (en) | 2010-06-08 |
Family
ID=38198608
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2588059A Expired - Fee Related CA2588059C (en) | 2004-11-22 | 2005-11-19 | Identification of the channel frequency response using chirps and stepped frequencies |
Country Status (3)
| Country | Link |
|---|---|
| CA (1) | CA2588059C (en) |
| GB (3) | GB2458396B (en) |
| NO (1) | NO338841B1 (en) |
Families Citing this family (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| EA035751B1 (en) | 2013-08-28 | 2020-08-05 | Эволюшн Инжиниринг Инк. | Optimizing electromagnetic telemetry transmissions |
| CN105784103B (en) * | 2016-01-22 | 2019-01-29 | 北京航空航天大学 | A kind of frequency characteristic measurement method of the change signal-to-noise ratio based on nonlinear frequency modulation excitation |
| US20220205959A1 (en) * | 2019-01-16 | 2022-06-30 | Massachusetts Institute Of Technology | Acoustic spectrometer |
Family Cites Families (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4314364A (en) * | 1979-07-26 | 1982-02-02 | Atlantic Richfield Company | Long sweep vibroseis record production |
| US5055837A (en) * | 1990-09-10 | 1991-10-08 | Teleco Oilfield Services Inc. | Analysis and identification of a drilling fluid column based on decoding of measurement-while-drilling signals |
| US5283768A (en) * | 1991-06-14 | 1994-02-01 | Baker Hughes Incorporated | Borehole liquid acoustic wave transducer |
| US5124953A (en) * | 1991-07-26 | 1992-06-23 | Teleco Oilfield Services Inc. | Acoustic data transmission method |
| DE19646164A1 (en) * | 1996-11-08 | 1998-05-14 | Deutsche Telekom Ag | Process for the transmission of digital signals |
| US6509866B2 (en) * | 2000-01-12 | 2003-01-21 | California Institute Of Technology | Fast chirp transform |
-
2005
- 2005-11-19 GB GB0910286A patent/GB2458396B/en active Active
- 2005-11-19 GB GB0910285A patent/GB2458395B/en active Active
- 2005-11-19 CA CA2588059A patent/CA2588059C/en not_active Expired - Fee Related
- 2005-11-19 GB GB0710317A patent/GB2435660B/en active Active
-
2007
- 2007-05-24 NO NO20072656A patent/NO338841B1/en unknown
Also Published As
| Publication number | Publication date |
|---|---|
| GB2435660A (en) | 2007-09-05 |
| NO338841B1 (en) | 2016-10-24 |
| GB2458396A (en) | 2009-09-23 |
| GB0910285D0 (en) | 2009-07-29 |
| CA2588059C (en) | 2010-06-08 |
| NO20072656L (en) | 2007-06-08 |
| GB0910286D0 (en) | 2009-07-29 |
| GB2435660B (en) | 2009-10-14 |
| GB2458395B (en) | 2009-11-04 |
| GB0710317D0 (en) | 2007-07-11 |
| GB2458396B (en) | 2009-11-04 |
| GB2458395A (en) | 2009-09-23 |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| EEER | Examination request | ||
| MKLA | Lapsed |
Effective date: 20211119 |