CA2601283A1 - System and method for real-time management of formation fluid sampling with a guarded probe - Google Patents
System and method for real-time management of formation fluid sampling with a guarded probe Download PDFInfo
- Publication number
- CA2601283A1 CA2601283A1 CA002601283A CA2601283A CA2601283A1 CA 2601283 A1 CA2601283 A1 CA 2601283A1 CA 002601283 A CA002601283 A CA 002601283A CA 2601283 A CA2601283 A CA 2601283A CA 2601283 A1 CA2601283 A1 CA 2601283A1
- Authority
- CA
- Canada
- Prior art keywords
- fluid sample
- probe
- property
- wellbore
- real
- 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
- 239000000523 sample Substances 0.000 title claims abstract 65
- 239000012530 fluid Substances 0.000 title claims abstract 57
- 238000000034 method Methods 0.000 title claims abstract 28
- 238000005070 sampling Methods 0.000 title claims abstract 24
- 230000015572 biosynthetic process Effects 0.000 title claims abstract 22
- 238000011109 contamination Methods 0.000 claims 6
- 238000013213 extrapolation Methods 0.000 claims 4
- 239000000126 substance Substances 0.000 claims 2
- 230000003247 decreasing effect Effects 0.000 claims 1
- 238000012544 monitoring process Methods 0.000 claims 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
- E21B49/00—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
- E21B49/08—Obtaining fluid samples or testing fluids, in boreholes or wells
- E21B49/10—Obtaining fluid samples or testing fluids, in boreholes or wells using side-wall fluid samplers or testers
-
- 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
- E21B49/00—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
- E21B49/08—Obtaining fluid samples or testing fluids, in boreholes or wells
- E21B49/087—Well testing, e.g. testing for reservoir productivity or formation parameters
- E21B49/088—Well testing, e.g. testing for reservoir productivity or formation parameters combined with sampling
Abstract
Embodiments of the present invention relate to systems and methods for real- time management of formation fluid sampling down a wellbore using a guarded probe. More specifically, but not by way of limitation, embodiments of the present invention provide for management of downhole fluid sampling by sensing properties of fluids collected by a downhole-fluid-sampling-device, modeling the fluid sampling process from these sensed properties and using the modeling of the fluid sampling process to manage in real-time the fluid sampling process.
Claims (34)
1. A method for real-time management of sampling of formation fluids from an earth formation surrounding a wellbore, the region of the formation immediately surrounding the wellbore being at least partially invaded by wellbore fluids, comprising:
withdrawing fluids from the earth formation;
sensing a physical or chemical property of the withdrawn fluids;
outputting a signal corresponding to the sensed physical or chemical property;
using the output signal to model properties of the withdrawn fluids; and using the modeled properties of the fluid sample for the real-time management of the sampling of the formation fluids.
withdrawing fluids from the earth formation;
sensing a physical or chemical property of the withdrawn fluids;
outputting a signal corresponding to the sensed physical or chemical property;
using the output signal to model properties of the withdrawn fluids; and using the modeled properties of the fluid sample for the real-time management of the sampling of the formation fluids.
2. The method of claim 1, wherein the modeling of the properties of the fluid sample comprises predicting properties of subsequently withdrawn fluids, wherein the subsequently withdrawn fluids comprise the formation fluids withdrawn from the earth formation subsequent to the sensing.
3. A method for real-time management of sampling of formation fluids from an earth formation surrounding a wellbore, the region of the formation immediately surrounding the wellbore being at least partially invaded by wellbore fluids, comprising:
lowering a wellbore tool with a fluid sampling device into the wellbore, the fluid sampling device comprising a sampling probe and a guard probe, wherein the sampling probe and the guard probe are adjacent to one another and wherein the sampling probe is configured for withdrawing a first fluid sample from the formation and the guard probe is configured for withdrawing a second fluid sample from the formation;
urging the fluid sampling device into contact with a wellbore wall;
withdrawing the first and the second fluid samples from the formation;
determining a first property of the first fluid sample;
determining a second property of the second fluid sample; and using a processor to process in real-time a delta value, wherein the delta value comprises a difference between the first property and the second property.
lowering a wellbore tool with a fluid sampling device into the wellbore, the fluid sampling device comprising a sampling probe and a guard probe, wherein the sampling probe and the guard probe are adjacent to one another and wherein the sampling probe is configured for withdrawing a first fluid sample from the formation and the guard probe is configured for withdrawing a second fluid sample from the formation;
urging the fluid sampling device into contact with a wellbore wall;
withdrawing the first and the second fluid samples from the formation;
determining a first property of the first fluid sample;
determining a second property of the second fluid sample; and using a processor to process in real-time a delta value, wherein the delta value comprises a difference between the first property and the second property.
4. The method of claim 3, wherein the sampling probe comprises an inner probe and the guard probe comprises an outer probe, and wherein the outer probe surrounds the inner probe.
5. The method of claim 3, wherein the sampling probe is maintained at a first pressure and the guard probe is maintained at a second pressure.
6. The method of claim 5, wherein the first pressure is higher than the second pressure.
7. The method of claim 3, wherein the first property is a first contamination amount of the first fluid sample and the second property is a second contamination amount of the second fluid sample.
8. The method of claim 4, further comprising:
identifying in real-time the existence of a maximum of the delta value.
identifying in real-time the existence of a maximum of the delta value.
9. The method of claim 5, further comprising:
collecting a portion of the first fluid sample.
collecting a portion of the first fluid sample.
10. The method of claim 5, further comprising:
determining in real-time that for a selected period of time after the identification of the maximum of the delta value the delta value is continuously decreasing.
determining in real-time that for a selected period of time after the identification of the maximum of the delta value the delta value is continuously decreasing.
11. The method of claim 7, further comprising:
collecting a portion of the first fluid sample.
collecting a portion of the first fluid sample.
12. The method of claim 3, further comprising:
displaying in real-time the processed delta value.
displaying in real-time the processed delta value.
13. The method of claim 3, wherein a single sensor is used to determine the first property of the first fluid sample and the second property of the second fluid sample.
14. The method of claim 3, further comprising:
normalizing a first initial value of the first property and a second initial value of the second property, wherein the first and the second initial values are values of the first and the second property when sampling from the formation commences.
normalizing a first initial value of the first property and a second initial value of the second property, wherein the first and the second initial values are values of the first and the second property when sampling from the formation commences.
15. The method of claim 4, further comprising:
using the delta value to mathematically model in real-time future properties of the first fluid sample; and adjusting the first pressure or the second pressure.
using the delta value to mathematically model in real-time future properties of the first fluid sample; and adjusting the first pressure or the second pressure.
16. The method of claim 3, further comprising:
extrapolating in real-time a first future property of the first fluid sample from the delta value.
extrapolating in real-time a first future property of the first fluid sample from the delta value.
17. The method of claim 16, further comprising:
using results from the extrapolation to determine when to collect a portion of the first fluid sample.
using results from the extrapolation to determine when to collect a portion of the first fluid sample.
18. The method of claim 3, further comprising:
extrapolating in real-time a second future property of the second fluid sample from the delta value.
extrapolating in real-time a second future property of the second fluid sample from the delta value.
19. The method of claim 16, further comprising:
using results from the extrapolation to determine when to collect a portion of the second fluid sample.
using results from the extrapolation to determine when to collect a portion of the second fluid sample.
20. The method of claim 19, further comprising:
using results from the extrapolation to determine when to collect a combined portion of the first and the second fluid sample.
using results from the extrapolation to determine when to collect a combined portion of the first and the second fluid sample.
21. The method of claim 3, wherein a single sensor is used to determine the first property of the first fluid sample and the second property of the second fluid sample.
22. A system for monitoring sampling of formation fluids from an earth formation surrounding a wellbore, the region of the formation immediately surrounding the wellbore being at least partially invaded by wellbore fluids, comprising:
a wellbore tool configured for use inside the wellbore;
a sampling probe coupled with the wellbore tool and configured for withdrawing a first fluid sample from the formation;
a guard probe coupled with the wellbore tool disposed adjacent to the sampling probe and configured for withdrawing a second fluid sample from the formation;
a first sensor configured to measure a first property of the first fluid sample;
a second sensor configured to measure a second property of the second fluid sample; and a processor configured to process in real-time a delta value, wherein the delta value comprises a difference between the first property and the second property.
a wellbore tool configured for use inside the wellbore;
a sampling probe coupled with the wellbore tool and configured for withdrawing a first fluid sample from the formation;
a guard probe coupled with the wellbore tool disposed adjacent to the sampling probe and configured for withdrawing a second fluid sample from the formation;
a first sensor configured to measure a first property of the first fluid sample;
a second sensor configured to measure a second property of the second fluid sample; and a processor configured to process in real-time a delta value, wherein the delta value comprises a difference between the first property and the second property.
23. The system of 22, wherein the processor is configured to extrapolate in real-time a first contamination value of the first fluid sample or a second contamination value of the second fluid sample using the delta value.
24. The system of 22, further comprising;
a collection container coupled with the sampling probe or the guard probe and configured for collecting a portion of the first or the second fluid sample.
a collection container coupled with the sampling probe or the guard probe and configured for collecting a portion of the first or the second fluid sample.
25. The system of 22, further comprising:
a collection container coupled with the first and the guard probe and configured for collecting a portion of the first and the second fluid sample.
a collection container coupled with the first and the guard probe and configured for collecting a portion of the first and the second fluid sample.
26. The system of 24, wherein the processor is configured to extrapolate in real-time a first contamination value of the first fluid sample or a second contamination value of the second fluid sample using the delta value, and wherein the processor is configured in real-time to control the collection container to collect a portion of the first or the second fluid sample based upon results of the extrapolation.
27. The system of claim 22, wherein the first and second sensor comprise a single sensor, and wherein the first fluid sample and the second fluid sample are provided separately to the single sensor for analysis.
28. The system of claim 22, wherein the sampling probe comprises an inner probe and the guard probe comprises an outer probe, and wherein the outer probe surrounds the inner probe.
29. The system of claim 22, wherein the sampling probe is maintained at a first pressure and the guard probe is maintained at a second pressure.
30. The system of claim 25, wherein the processor controls the first and the second pressure.
31. The system of claim 22, wherein the wellbore tool is configured for use on a wireline or a drillstring.
32. The system of claim 22, wherein the first and the guard probe are configured to penetrate through the wellbore wall.
33. The system of claim 22, wherein the first and the guard probe are configured to penetrate the formation.
34. The system of claim 22, further comprising:
an interface coupled with the wellbore tool and configured to display an output from the processor.
an interface coupled with the wellbore tool and configured to display an output from the processor.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US11/534,472 | 2006-09-22 | ||
| US11/534,472 US7757760B2 (en) | 2006-09-22 | 2006-09-22 | System and method for real-time management of formation fluid sampling with a guarded probe |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2601283A1 true CA2601283A1 (en) | 2008-03-22 |
| CA2601283C CA2601283C (en) | 2010-11-23 |
Family
ID=38566405
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2601283A Active CA2601283C (en) | 2006-09-22 | 2007-09-11 | System and method for real-time management of formation fluid sampling with a guarded probe |
Country Status (3)
| Country | Link |
|---|---|
| US (1) | US7757760B2 (en) |
| CA (1) | CA2601283C (en) |
| GB (1) | GB2442087B (en) |
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| GB2442639B (en) * | 2005-10-26 | 2008-09-17 | Schlumberger Holdings | Downhole sampling apparatus and method for using same |
| US7857049B2 (en) * | 2006-09-22 | 2010-12-28 | Schlumberger Technology Corporation | System and method for operational management of a guarded probe for formation fluid sampling |
| WO2009138911A2 (en) * | 2008-05-13 | 2009-11-19 | Schlumberger Canada Limited | Methods and apparatus for characterization of petroleum fluids contaminated with drilling mud |
| US8099241B2 (en) * | 2008-12-29 | 2012-01-17 | Schlumberger Technology Corporation | Method and apparatus for real time oil based mud contamination monitoring |
| US8165817B2 (en) * | 2009-03-09 | 2012-04-24 | Schlumberger Technology Corporation | Method for integrating reservoir charge modeling and downhole fluid analysis |
| US20110214879A1 (en) * | 2010-03-03 | 2011-09-08 | Baker Hughes Incorporated | Tactile pressure sensing devices and methods for using same |
| CA2821727A1 (en) | 2010-12-20 | 2012-06-28 | Pierre-Yves Corre | Sampling assembly for a single packer |
| US9507047B1 (en) | 2011-05-10 | 2016-11-29 | Ingrain, Inc. | Method and system for integrating logging tool data and digital rock physics to estimate rock formation properties |
| US8905131B2 (en) * | 2011-09-13 | 2014-12-09 | Schlumberger Technology Corporation | Probeless packer and filter systems |
| US10221686B2 (en) * | 2011-09-13 | 2019-03-05 | Halliburton Energy Services, Inc. | Measuring an adsorbing chemical in downhole fluids |
| MX363305B (en) * | 2013-01-03 | 2019-03-20 | Halliburton Energy Services Inc | System and method for collecting a representative formation fluid during downhole testing operations. |
| US9284838B2 (en) | 2013-02-14 | 2016-03-15 | Baker Hughes Incorporated | Apparatus and method for obtaining formation fluid samples utilizing independently controlled devices on a common hydraulic line |
| US9752432B2 (en) * | 2013-09-10 | 2017-09-05 | Schlumberger Technology Corporation | Method of formation evaluation with cleanup confirmation |
| US10083258B2 (en) * | 2013-09-13 | 2018-09-25 | Schlumberger Technology Corporation | Combining downhole fluid analysis and petroleum systems modeling |
| US10215022B2 (en) | 2013-12-19 | 2019-02-26 | Schlumberger Technology Corporation | Guard filtering system for focused sampling probe |
| US10858935B2 (en) * | 2014-01-27 | 2020-12-08 | Schlumberger Technology Corporation | Flow regime identification with filtrate contamination monitoring |
| US10577928B2 (en) | 2014-01-27 | 2020-03-03 | Schlumberger Technology Corporation | Flow regime identification with filtrate contamination monitoring |
| US10585082B2 (en) * | 2015-04-30 | 2020-03-10 | Schlumberger Technology Corporation | Downhole filtrate contamination monitoring |
| US10725203B2 (en) | 2015-11-18 | 2020-07-28 | Halliburton Energy Services, Inc. | Dual-sensor tool optical data processing through master sensor standardization |
| TWI621520B (en) * | 2016-07-14 | 2018-04-21 | 東友科技股份有限公司 | Exposure molding device and exposure molding method thereof |
| AU2020292349A1 (en) * | 2019-06-14 | 2022-02-03 | Chevron U.S.A. Inc. | Systems and methods for sampling chemical species in various environments |
| CN110905493B (en) * | 2019-11-21 | 2023-05-12 | 中国海洋石油集团有限公司 | Method for measuring pollution rate of underground stratum fluid |
| US20240093595A1 (en) * | 2022-09-16 | 2024-03-21 | Halliburton Energy Services, Inc. | Inorganic Scale Detection Or Scaling Potential Downhole |
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-
2006
- 2006-09-22 US US11/534,472 patent/US7757760B2/en active Active
-
2007
- 2007-08-15 GB GB0715884A patent/GB2442087B/en active Active
- 2007-09-11 CA CA2601283A patent/CA2601283C/en active Active
Also Published As
| Publication number | Publication date |
|---|---|
| GB2442087B (en) | 2009-05-06 |
| US20080125973A1 (en) | 2008-05-29 |
| GB0715884D0 (en) | 2007-09-26 |
| CA2601283C (en) | 2010-11-23 |
| GB2442087A (en) | 2008-03-26 |
| US7757760B2 (en) | 2010-07-20 |
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