CA2591485A1 - Two sensor impedance estimation for uplink telemetry signals - Google Patents
Two sensor impedance estimation for uplink telemetry signals Download PDFInfo
- Publication number
- CA2591485A1 CA2591485A1 CA002591485A CA2591485A CA2591485A1 CA 2591485 A1 CA2591485 A1 CA 2591485A1 CA 002591485 A CA002591485 A CA 002591485A CA 2591485 A CA2591485 A CA 2591485A CA 2591485 A1 CA2591485 A1 CA 2591485A1
- Authority
- CA
- Canada
- Prior art keywords
- signals
- positions
- message
- signal
- message signal
- 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
- 238000005259 measurement Methods 0.000 claims abstract 3
- 239000012530 fluid Substances 0.000 claims 14
- 238000000034 method Methods 0.000 claims 10
- 238000001914 filtration Methods 0.000 claims 3
- 230000010363 phase shift Effects 0.000 claims 3
- 230000015572 biosynthetic process Effects 0.000 claims 2
- 238000005553 drilling Methods 0.000 claims 1
- 230000003287 optical effect Effects 0.000 claims 1
- 230000009977 dual effect Effects 0.000 abstract 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
Abstract
Measurements made with dual sensors (flow rate or pressure) are used to attenuate pump noise in a mud pulse telemetry system.
Claims (26)
1. A method of communicating a signal through a fluid in a borehole between a first location and a second location, the method comprising:
(a) measuring first and second signals in the fluid at spaced apart first and second positions at or near the second location in response to operation of at least one of (A) a noise source, and (B) a message source at the first location;
(b) estimating from the first and second signals a characteristic of a fluid channel between the first and second positions;
(c) generating a message signal at the first location simultaneously with operation of the noise source;
(d) measuring third and fourth signals at the first and second positions responsive to the message signal and the simultaneous operation of the noise source; and (e) estimating the message signal from the third and fourth signals and the estimated fluid channel characteristic
(a) measuring first and second signals in the fluid at spaced apart first and second positions at or near the second location in response to operation of at least one of (A) a noise source, and (B) a message source at the first location;
(b) estimating from the first and second signals a characteristic of a fluid channel between the first and second positions;
(c) generating a message signal at the first location simultaneously with operation of the noise source;
(d) measuring third and fourth signals at the first and second positions responsive to the message signal and the simultaneous operation of the noise source; and (e) estimating the message signal from the third and fourth signals and the estimated fluid channel characteristic
2. The method of claim 1 wherein the first and second signals comprise at least one of (i) a pressure signal, and (ii) a flow rate signal.
3. The method of claim 1 wherein the noise source is on a side of the first and second positions opposite to the first location.
4. The method of claim 1 wherein the characteristic of the fluid comprises a transfer function between at least one of (i) the first and second positions, and (ii) the second and first positions.
5. The method of claim 1 wherein estimating the characteristic of the fluid channel further comprises performing a unitary transform of the first and second signals.
6. The method of claim 1 wherein the unitary transform comprises a Fourier transform.
7. The method of claim 1 wherein estimating the message signal further comprises performing a differential filtering based on one of (i) a zero forcing, and (ii) a least squares minimization.
8. The method of claim 1 wherein generating the message signal further comprises at least one of (i) Amplitude Shift Keying (ASK), (ii) Frequency Shift Keying (FSK), and, (iii) Phase Shift Keying (PSK).
9. The method of claim 1 wherein the message signal further comprises a swept frequency signal.
10. A system for communicating a signal through a fluid in a borehole between a bottomhole assembly (BHA) and a surface location, the system comprising:
(a) a message source on the bottomhole assembly (BHA) capable of generating a message signal;
(b) first and second sensors at spaced apart first and second positions that measure first and second signals in response to operation of at least one of (A) a noise source, and, (B) the message source; and (c) a processor which estimates from the first and second signals a characteristic of a fluid channel between the first and second positions;
wherein the first and second sensors further receive third and fourth signals responsive to a message signal at the downhole location generated simultaneously with operation of the noise source; and wherein the processor further estimates the message signal from the third and fourth signals and the estimated fluid characteristic
(a) a message source on the bottomhole assembly (BHA) capable of generating a message signal;
(b) first and second sensors at spaced apart first and second positions that measure first and second signals in response to operation of at least one of (A) a noise source, and, (B) the message source; and (c) a processor which estimates from the first and second signals a characteristic of a fluid channel between the first and second positions;
wherein the first and second sensors further receive third and fourth signals responsive to a message signal at the downhole location generated simultaneously with operation of the noise source; and wherein the processor further estimates the message signal from the third and fourth signals and the estimated fluid characteristic
11. The system of claim 10 wherein the first and second signals are selected from the group consisting of (i) a pressure signal, and, (ii) a flow rate signal.
12. The system of claim 10 wherein the noise source is on a side of the first and second positions opposite to the message source.
13. The system of claim 10 wherein the characteristic of the fluid channel comprises a transfer function between at least one of (i) the first and second positions, and (ii) the second and first positions.
14. The system of claim 10 wherein in estimating the characteristic of the fluid channel the processor further performs a unitary transform of the first and second signals.
15. The system of claim 14 wherein the unitary transform comprises a Fourier transform.
16. The system of claim 10 wherein in estimating the message signal the processor further performs a differential filtering based on one of (i) a zero forcing, and (ii) a least squares minimization..
17. The system of claim 10 wherein generating the message signal further comprises at least one of (i) Amplitude Shift Keying (ASK), (ii) Frequency Shift Keying (FSK), and, (iii) Phase Shift Keying (PSK).
18. The system of claim 10 wherein the message signal further comprises a swept frequency signal.
19. The system of claim 10 wherein the BHA is conveyed on a drilling tubular.
20. The system of claim 10 wherein the message source comprises an oscillating valve.
21. A machine readable medium for use in conjunction with a bottomhole assembly (BHA), conveyed in a borehole in an earth formation, the medium comprising instructions for:
(a) estimating from first and second signals in a fluid at spaced apart first and second positions at or near a surface location in response to operation of at least one of (A) a noise source, and, (B) a message source at the downhole location, a characteristic of a fluid channel between the first and second positions;
(c) estimating a value of a message signal generated at the BHA
simultaneously with operation of the noise source from:
(A) third and fourth signals measured at the first and second positions responsive to the message signal and the simultaneous operation of the noise source, and (B) the estimated fluid channel characteristic.
(a) estimating from first and second signals in a fluid at spaced apart first and second positions at or near a surface location in response to operation of at least one of (A) a noise source, and, (B) a message source at the downhole location, a characteristic of a fluid channel between the first and second positions;
(c) estimating a value of a message signal generated at the BHA
simultaneously with operation of the noise source from:
(A) third and fourth signals measured at the first and second positions responsive to the message signal and the simultaneous operation of the noise source, and (B) the estimated fluid channel characteristic.
22. The machine readable medium of claim 21 further comprises at least one of (i) a ROM, (ii) an EPROM, (iii) an EAROM, (iv) a Flash Memory, and, (v) an optical disk.
23. The machine readable medium of claim 21 further comprising instructions for performing a unitary transform of the first and second signals.
24. The machine readable medium of claim 21 further comprising instructions for performing a differential filtering.
25. The machine readable medium of claim 21 wherein generating the message signal further comprises at least one of (i) Amplitude Shift Keying (ASK), (ii) Frequency Shift Keying (FSK), and, (iii) Phase Shift Keying (PSK).
26. The machine readable medium of claim 21 further comprising instructions for generating the message signal in response to at least one of (i) a measurement of a parameter of the BHA, and, (ii) a measurement of a property of the earth formation.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US11/018,344 | 2004-12-21 | ||
| US11/018,344 US20060132327A1 (en) | 2004-12-21 | 2004-12-21 | Two sensor impedance estimation for uplink telemetry signals |
| PCT/US2005/046152 WO2006069060A1 (en) | 2004-12-21 | 2005-12-20 | Two sensor impedance estimation for uplink telemetry signals |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2591485A1 true CA2591485A1 (en) | 2006-06-29 |
| CA2591485C CA2591485C (en) | 2010-09-07 |
Family
ID=36123572
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2591485A Active CA2591485C (en) | 2004-12-21 | 2005-12-20 | Two sensor impedance estimation for uplink telemetry signals |
Country Status (5)
| Country | Link |
|---|---|
| US (2) | US20060132327A1 (en) |
| CA (1) | CA2591485C (en) |
| GB (1) | GB2437209B (en) |
| NO (1) | NO341592B1 (en) |
| WO (1) | WO2006069060A1 (en) |
Families Citing this family (13)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| NO320229B1 (en) * | 2004-06-24 | 2005-11-14 | Nat Oilwell Norway As | Procedure for canceling pump noise by well telemetry |
| US8004421B2 (en) * | 2006-05-10 | 2011-08-23 | Schlumberger Technology Corporation | Wellbore telemetry and noise cancellation systems and method for the same |
| WO2007149324A2 (en) * | 2006-06-16 | 2007-12-27 | Baker Hughes Incorporated | Estimation of properties of mud |
| US8009511B2 (en) * | 2006-08-11 | 2011-08-30 | Baker Hughes Incorporated | Pressure waves decoupling with two transducers |
| US7508734B2 (en) * | 2006-12-04 | 2009-03-24 | Halliburton Energy Services, Inc. | Method and apparatus for acoustic data transmission in a subterranean well |
| US20080231466A1 (en) * | 2007-03-19 | 2008-09-25 | Halliburton Energy Services, Inc. | Facilitating the communication of connectively dissimilar well servicing industry equipment via a universal connection device |
| US9726010B2 (en) * | 2007-07-13 | 2017-08-08 | Baker Hughes Incorporated | Estimation of multichannel mud characteristics |
| US8154419B2 (en) * | 2007-12-14 | 2012-04-10 | Halliburton Energy Services Inc. | Oilfield area network communication system and method |
| US8616274B2 (en) | 2010-05-07 | 2013-12-31 | Halliburton Energy Services, Inc. | System and method for remote wellbore servicing operations |
| US20130020074A1 (en) * | 2011-03-24 | 2013-01-24 | Baker Hughes Incorporated | Apparatus and method for filtering data influenced by a downhole pump |
| DE102012109556B4 (en) | 2012-10-09 | 2014-08-21 | Gottfried Wilhelm Leibniz Universität Hannover | Method and system for transmitting data in a wellbore and mobile unit and base unit thereto |
| AU2014413657B2 (en) | 2014-12-10 | 2018-04-19 | Halliburton Energy Services, Inc. | Devices and methods for filtering pump interference in mud pulse telemetry |
| CN107465399B (en) * | 2017-08-17 | 2023-06-13 | 中天启明石油技术有限公司 | Device and method for calculating fundamental wave frequency of pump flushing noise in logging while drilling |
Family Cites Families (20)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US3742443A (en) * | 1970-07-27 | 1973-06-26 | Mobil Oil Corp | Apparatus for improving signal-to-noise ratio in logging-while-drilling system |
| US3747059A (en) * | 1970-12-18 | 1973-07-17 | Schlumberger Technology Corp | Electronic noise filter with means for compensating for hose reflection |
| US3716830A (en) * | 1970-12-18 | 1973-02-13 | D Garcia | Electronic noise filter with hose reflection suppression |
| US4692911A (en) * | 1977-12-05 | 1987-09-08 | Scherbatskoy Serge Alexander | Methods and apparatus for reducing interfering effects in measurement while drilling operations |
| US5113379A (en) * | 1977-12-05 | 1992-05-12 | Scherbatskoy Serge Alexander | Method and apparatus for communicating between spaced locations in a borehole |
| US4262343A (en) * | 1979-04-18 | 1981-04-14 | Dresser Industries | Pressure pulse detection apparatus |
| CA1189442A (en) * | 1981-11-09 | 1985-06-25 | Gary D. Berkenkamp | Pump noise filtering apparatus for a borehole measurement while drilling system utilizing drilling fluid pressure sensing |
| US4642800A (en) * | 1982-08-23 | 1987-02-10 | Exploration Logging, Inc. | Noise subtraction filter |
| US4590593A (en) * | 1983-06-30 | 1986-05-20 | Nl Industries, Inc. | Electronic noise filtering system |
| US4715022A (en) * | 1985-08-29 | 1987-12-22 | Scientific Drilling International | Detection means for mud pulse telemetry system |
| US5128901A (en) * | 1988-04-21 | 1992-07-07 | Teleco Oilfield Services Inc. | Acoustic data transmission through a drillstring |
| US5146433A (en) * | 1991-10-02 | 1992-09-08 | Anadrill, Inc. | Mud pump noise cancellation system and method |
| US5969638A (en) * | 1998-01-27 | 1999-10-19 | Halliburton Energy Services, Inc. | Multiple transducer MWD surface signal processing |
| US5963138A (en) | 1998-02-05 | 1999-10-05 | Baker Hughes Incorporated | Apparatus and method for self adjusting downlink signal communication |
| US6370082B1 (en) * | 1999-06-14 | 2002-04-09 | Halliburton Energy Services, Inc. | Acoustic telemetry system with drilling noise cancellation |
| GB2361789B (en) | 1999-11-10 | 2003-01-15 | Schlumberger Holdings | Mud pulse telemetry receiver |
| EP1192482A4 (en) * | 2000-05-08 | 2009-11-11 | Schlumberger Holdings | Digital signal receiver for measurement while drilling system having noise cancellation |
| US6626253B2 (en) * | 2001-02-27 | 2003-09-30 | Baker Hughes Incorporated | Oscillating shear valve for mud pulse telemetry |
| US7324010B2 (en) * | 2004-11-09 | 2008-01-29 | Halliburton Energy Services, Inc. | Acoustic telemetry systems and methods with surface noise cancellation |
| US20060114746A1 (en) * | 2004-11-29 | 2006-06-01 | Halliburton Energy Services, Inc. | Acoustic telemetry system using passband equalization |
-
2004
- 2004-12-21 US US11/018,344 patent/US20060132327A1/en not_active Abandoned
-
2005
- 2005-12-19 US US11/311,196 patent/US7423550B2/en active Active
- 2005-12-20 GB GB0713997A patent/GB2437209B/en active Active
- 2005-12-20 WO PCT/US2005/046152 patent/WO2006069060A1/en active Application Filing
- 2005-12-20 CA CA2591485A patent/CA2591485C/en active Active
-
2007
- 2007-06-22 NO NO20073164A patent/NO341592B1/en unknown
Also Published As
| Publication number | Publication date |
|---|---|
| US20060132328A1 (en) | 2006-06-22 |
| GB2437209A (en) | 2007-10-17 |
| GB0713997D0 (en) | 2007-08-29 |
| GB2437209B (en) | 2009-02-25 |
| WO2006069060A1 (en) | 2006-06-29 |
| US7423550B2 (en) | 2008-09-09 |
| US20060132327A1 (en) | 2006-06-22 |
| NO20073164L (en) | 2007-06-26 |
| CA2591485C (en) | 2010-09-07 |
| NO341592B1 (en) | 2017-12-11 |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| EEER | Examination request |