CA2463276A1 - Real-time on-line sensing and control of mineral scale deposition from formation fluids - Google Patents
Real-time on-line sensing and control of mineral scale deposition from formation fluids Download PDFInfo
- Publication number
- CA2463276A1 CA2463276A1 CA002463276A CA2463276A CA2463276A1 CA 2463276 A1 CA2463276 A1 CA 2463276A1 CA 002463276 A CA002463276 A CA 002463276A CA 2463276 A CA2463276 A CA 2463276A CA 2463276 A1 CA2463276 A1 CA 2463276A1
- Authority
- CA
- Canada
- Prior art keywords
- probe
- mineral scale
- formation fluid
- scale deposition
- refractive index
- 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
- 239000012530 fluid Substances 0.000 title claims abstract 26
- 230000008021 deposition Effects 0.000 title claims abstract 25
- 229910052500 inorganic mineral Inorganic materials 0.000 title claims abstract 25
- 239000011707 mineral Substances 0.000 title claims abstract 25
- 230000015572 biosynthetic process Effects 0.000 title claims abstract 24
- 239000000523 sample Substances 0.000 claims abstract 36
- 238000000034 method Methods 0.000 claims abstract 21
- 239000000654 additive Substances 0.000 claims abstract 3
- 230000003287 optical effect Effects 0.000 claims 5
- 239000000463 material Substances 0.000 claims 4
- 239000003129 oil well Substances 0.000 claims 4
- 230000000996 additive effect Effects 0.000 claims 2
- 238000004140 cleaning Methods 0.000 claims 2
- 230000003247 decreasing effect Effects 0.000 claims 1
- 238000005102 attenuated total reflection Methods 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
- E21B37/00—Methods or apparatus for cleaning boreholes or wells
- E21B37/06—Methods or apparatus for cleaning boreholes or wells using chemical means for preventing, limiting or eliminating the deposition of paraffins or like substances
-
- 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
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N21/00—Investigating or analysing materials by the use of optical means, i.e. using sub-millimetre waves, infrared, visible or ultraviolet light
- G01N21/17—Systems in which incident light is modified in accordance with the properties of the material investigated
- G01N21/41—Refractivity; Phase-affecting properties, e.g. optical path length
- G01N21/43—Refractivity; Phase-affecting properties, e.g. optical path length by measuring critical angle
- G01N21/431—Dip refractometers, e.g. using optical fibres
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N21/00—Investigating or analysing materials by the use of optical means, i.e. using sub-millimetre waves, infrared, visible or ultraviolet light
- G01N21/17—Systems in which incident light is modified in accordance with the properties of the material investigated
- G01N21/55—Specular reflectivity
- G01N21/552—Attenuated total reflection
Abstract
The present invention provides a method and system for controlling mineral scale deposition from a formation fluid. The rate at which scaling is occuring is measured in real time using an attenuated total reflectance probe and a photometer. The results are then used to determine whether to increase, decrease or leave unchanged addition of anti-scaling additives.
Claims (21)
1. ~A method for real time determination the of mineral scale deposition rate from a formation fluid comprising:
A) placing an optical probe having a probe surface which can measure changes in refractive index at the probe surface, into contact with a formation fluid produced or being produced from an oil well;
B) measuring the changes in refractive index at the probe surface; and C) determining the on-set and rate, if any, of mineral scale deposition from the formation fluid as a function of the changes in refractive index at the probe surface;
wherein:
i) the probe surface which can be monitored for changes in refractive index is in contact with the formation fluid;
ii) the probe, including the probe surface which can be monitored for changes in refractive index, is composed of a material which can withstand an extended period of contact with the formation fluid at the temperatures and pressures present in oil wells; and iii) the determination of on-set of mineral scale deposition and the mineral scale deposition rate from the formation fluid takes place in real time.
A) placing an optical probe having a probe surface which can measure changes in refractive index at the probe surface, into contact with a formation fluid produced or being produced from an oil well;
B) measuring the changes in refractive index at the probe surface; and C) determining the on-set and rate, if any, of mineral scale deposition from the formation fluid as a function of the changes in refractive index at the probe surface;
wherein:
i) the probe surface which can be monitored for changes in refractive index is in contact with the formation fluid;
ii) the probe, including the probe surface which can be monitored for changes in refractive index, is composed of a material which can withstand an extended period of contact with the formation fluid at the temperatures and pressures present in oil wells; and iii) the determination of on-set of mineral scale deposition and the mineral scale deposition rate from the formation fluid takes place in real time.
2. ~The method of Claim 1 wherein the optical probe having a probe surface which can measure changes in refractive index at the probe surface is an ATR probe.
3. ~The method of Claim 2 wherein the ATR probe includes a means of measuring the refractive index change associated with a material in contact with the probe which is a photometer.
4. ~The method of Claim 3 wherein the photometer measures light in a wavelength range of from 400 to 1500 nanometers.
5. ~The method of Claim 4 wherein the photometer measures light in a wavelength range of from 500 to 700 nanometers.
6. ~The method of Claim 5 wherein the photometer measures light in a wavelength range of from 630 to 690 nanometers.
7. ~The method of Claim 4 wherein the photometer measures light in a wavelength range of from 800 to 900 nanometers.
8. ~The method of Claim 7 wherein the photometer measures light in a wavelength range of from 850 to 900 nanometers.
9. ~The method of Claim 8 wherein the photometer measures light in a wavelength range of from 870 to 890 nanometers.
10. ~The method of Claim 1 additionally comprising using an automated probe cleaning device to clean, calibrate, insert and extract the probe surface.
11. ~A method for controlling mineral scale deposition from a formation fluid comprising:
A) placing an optical probe having a probe surface which can measure changes in refractive index at the probe surface, into contact with a formation fluid produced or being produced from an oil well;
B) measuring the changes in refractive index at the probe surface;
C) determining the on-set and rate, if any, of mineral scale deposition from the formation fluid as a function of the changes in refractive index at the probe surface;
D) comparing the rate, if any, of mineral scale deposition, to a predetermined range of acceptable mineral scale deposition; and E) effecting a change in the rate of addition, if any, to the formation fluid of an additive effective for preventing mineral scale deposition from a formation fluid ;
wherein:
i) the probe surface which can be monitored for changes in refractive index is in contact with the formation fluid;
ii) the probe, including the probe surface which can be monitored for changes in refractive index, is composed of a material which can withstand an extended period of contact with the formation fluid at the temperatures and pressures present in oil wells;~
iii) the determination of the mineral scale deposition rate from the formation fluid takes place in real time; and iv) the rate of addition, if any, to the formation fluid of the additive effective for preventing mineral scale deposition from a formation fluid is:
(1) increased when on-set of mineral scale deposition is detected or the mineral scale deposition rate is greater than the range of acceptable mineral scale deposition;
(2) decreased when no mineral scale deposition is detected or the mineral scale deposition rate is less than the range of acceptable mineral scale deposition; and (3) unchanged when no mineral scale deposition is detected or the mineral scale rate deposition is within the range of acceptable mineral scale deposition.
A) placing an optical probe having a probe surface which can measure changes in refractive index at the probe surface, into contact with a formation fluid produced or being produced from an oil well;
B) measuring the changes in refractive index at the probe surface;
C) determining the on-set and rate, if any, of mineral scale deposition from the formation fluid as a function of the changes in refractive index at the probe surface;
D) comparing the rate, if any, of mineral scale deposition, to a predetermined range of acceptable mineral scale deposition; and E) effecting a change in the rate of addition, if any, to the formation fluid of an additive effective for preventing mineral scale deposition from a formation fluid ;
wherein:
i) the probe surface which can be monitored for changes in refractive index is in contact with the formation fluid;
ii) the probe, including the probe surface which can be monitored for changes in refractive index, is composed of a material which can withstand an extended period of contact with the formation fluid at the temperatures and pressures present in oil wells;~
iii) the determination of the mineral scale deposition rate from the formation fluid takes place in real time; and iv) the rate of addition, if any, to the formation fluid of the additive effective for preventing mineral scale deposition from a formation fluid is:
(1) increased when on-set of mineral scale deposition is detected or the mineral scale deposition rate is greater than the range of acceptable mineral scale deposition;
(2) decreased when no mineral scale deposition is detected or the mineral scale deposition rate is less than the range of acceptable mineral scale deposition; and (3) unchanged when no mineral scale deposition is detected or the mineral scale rate deposition is within the range of acceptable mineral scale deposition.
12. The method of Claim 11 wherein the optical probe having a probe surface which can measure changes in refractive index at the probe surface is an ATR probe.
13. ~The method of Claim 12 wherein the ATR probe includes a means of measuring the refractance of a material in contact with the probe which is a photometer.
14. ~The method of Claim 13 wherein the photometer measures light in a wavelength range of from 400 to 1500 nanometers.
15. ~The method of Claim 14 wherein the photometer measures light in a wavelength range of from 500 to 700 nanometers.
16. ~The method of Claim 15 wherein the photometer measures light in a wavelength range of from 630 to 690 nanometers.
17. ~The method of Claim 14 wherein the photometer measures light in a wavelength range of from 800 to 900 nanometers.
18. ~The method of Claim 17 wherein the photometer measures light in a wavelength range of from 850 to 900 nanometers.
19. ~The method of Claim 18 wherein the photometer measures light in a wavelength range of from 870 to 890 nanometers.
20. ~The method of Claim 11 additionally comprising using an automated probe cleaning device to clean, calibrate, extract and insert the probe surface.
21. A system for controlling mineral scale deposition from a formation fluid comprising a fluid flow path for flowing formation fluid recovered from a subsurface formation; an optical probe having a probe surface which can measure changes in refractive index at the probe surface, associated with the formation fluid in the fluid flow path providing data corresponding to the rate of deposition of mineral scale from the formation fluid in the fluid flow path;
and a processor for determining from the data the rate of deposition of mineral scale from the formation fluid.
and a processor for determining from the data the rate of deposition of mineral scale from the formation fluid.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US09/975,161 | 2001-10-11 | ||
| US09/975,161 US6891606B2 (en) | 2001-10-11 | 2001-10-11 | Real-time on-line sensing and control of mineral scale deposition from formation fluids |
| PCT/US2002/005160 WO2003031950A1 (en) | 2001-10-11 | 2002-02-21 | Real-time on-line sensing and control of mineral scale deposition from formation fluids |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2463276A1 true CA2463276A1 (en) | 2003-04-17 |
| CA2463276C CA2463276C (en) | 2010-10-19 |
Family
ID=25522747
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2463276A Expired - Fee Related CA2463276C (en) | 2001-10-11 | 2002-02-21 | Real-time on-line sensing and control of mineral scale deposition from formation fluids |
Country Status (10)
| Country | Link |
|---|---|
| US (1) | US6891606B2 (en) |
| EP (1) | EP1434980B1 (en) |
| AT (1) | ATE489616T1 (en) |
| BR (1) | BRPI0212913B8 (en) |
| CA (1) | CA2463276C (en) |
| DE (1) | DE60238427D1 (en) |
| EA (1) | EA005707B1 (en) |
| MX (1) | MXPA04003271A (en) |
| NO (1) | NO336313B1 (en) |
| WO (1) | WO2003031950A1 (en) |
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| DE10208214B4 (en) * | 2002-02-26 | 2004-09-30 | BSH Bosch und Siemens Hausgeräte GmbH | Device for checking the formation of deposits and water-carrying device |
| US6927846B2 (en) * | 2003-07-25 | 2005-08-09 | Baker Hughes Incorporated | Real-time on-line sensing and control of emulsions in formation fluids |
| US7274443B2 (en) | 2003-12-10 | 2007-09-25 | Custom Sensors And Technology | Corrosion monitoring system, optical corrosion probe, and methods of use |
| WO2005062986A2 (en) * | 2003-12-31 | 2005-07-14 | The University Of South Carolina | Thin-layer porous optical sensors for gases and other fluids |
| US6997055B2 (en) * | 2004-05-26 | 2006-02-14 | Baker Hughes Incorporated | System and method for determining formation fluid parameters using refractive index |
| US20070201136A1 (en) * | 2004-09-13 | 2007-08-30 | University Of South Carolina | Thin Film Interference Filter and Bootstrap Method for Interference Filter Thin Film Deposition Process Control |
| WO2006063094A1 (en) * | 2004-12-09 | 2006-06-15 | Caleb Brett Usa Inc. | In situ optical computation fluid analysis system and method |
| WO2007064575A1 (en) | 2005-11-28 | 2007-06-07 | Ometric Corporation | Optical analysis system and method for real time multivariate optical computing |
| US8345234B2 (en) * | 2005-11-28 | 2013-01-01 | Halliburton Energy Services, Inc. | Self calibration methods for optical analysis system |
| US20070166245A1 (en) | 2005-11-28 | 2007-07-19 | Leonard Mackles | Propellant free foamable toothpaste composition |
| US8358418B2 (en) * | 2005-11-28 | 2013-01-22 | Halliburton Energy Services, Inc. | Optical analysis system for dynamic real-time detection and measurement |
| GB0603036D0 (en) * | 2006-02-15 | 2006-03-29 | Farfield Sensors Ltd | Method |
| WO2007120553A2 (en) * | 2006-04-10 | 2007-10-25 | Baker Hughes Incorporated | System and method for estimating filtrate contamination in formation fluid samples using refractive index |
| EP2033196A2 (en) | 2006-06-26 | 2009-03-11 | University of South Carolina | Data validation and classification in optical analysis systems |
| WO2008057912A2 (en) * | 2006-11-02 | 2008-05-15 | University Of South Carolina | Multi-analyte optical computing system |
| WO2008121684A1 (en) * | 2007-03-30 | 2008-10-09 | University Of South Carolina | Novel multi-analyte optical computing system |
| US8184295B2 (en) * | 2007-03-30 | 2012-05-22 | Halliburton Energy Services, Inc. | Tablet analysis and measurement system |
| US8212216B2 (en) * | 2007-03-30 | 2012-07-03 | Halliburton Energy Services, Inc. | In-line process measurement systems and methods |
| US8283633B2 (en) * | 2007-11-30 | 2012-10-09 | Halliburton Energy Services, Inc. | Tuning D* with modified thermal detectors |
| US8212213B2 (en) * | 2008-04-07 | 2012-07-03 | Halliburton Energy Services, Inc. | Chemically-selective detector and methods relating thereto |
| US8430162B2 (en) * | 2009-05-29 | 2013-04-30 | Schlumberger Technology Corporation | Continuous downhole scale monitoring and inhibition system |
| US20110146992A1 (en) * | 2009-12-22 | 2011-06-23 | Baker Hughes Incorporated | Controllable Chemical Injection For Multiple Zone Completions |
| US9760328B2 (en) | 2010-04-30 | 2017-09-12 | Ricoh Company, LLC | White space management mechanism |
| CA2801549A1 (en) * | 2010-06-04 | 2011-12-08 | Dow Global Technologies Llc | Method for determining scale deposition in enclosed spaces using fluorescence |
| CH704900A1 (en) * | 2011-05-05 | 2012-11-15 | Nemo Devices Ag | Measuring device for measuring cerebral parameters. |
| US9297767B2 (en) * | 2011-10-05 | 2016-03-29 | Halliburton Energy Services, Inc. | Downhole species selective optical fiber sensor systems and methods |
| US10060250B2 (en) | 2012-03-13 | 2018-08-28 | Halliburton Energy Services, Inc. | Downhole systems and methods for water source determination |
| US9377450B2 (en) * | 2012-06-22 | 2016-06-28 | Baker Hughes Incorporated | Process for predicting the stability of crude oil and employing same in transporting and/or refining the crude oil |
| US20140000889A1 (en) * | 2012-06-28 | 2014-01-02 | Baker Hughes Incorporated | Wireline flow through remediation tool |
| US9441481B2 (en) * | 2012-06-29 | 2016-09-13 | Schlumberger Technology Corporation | Method and apparatus for identifying fluid attributes |
| CH707194A1 (en) | 2012-11-06 | 2014-05-15 | Nemodevices Ag | Measuring device for determining cerebral parameters. |
| US9239406B2 (en) | 2012-12-18 | 2016-01-19 | Halliburton Energy Services, Inc. | Downhole treatment monitoring systems and methods using ion selective fiber sensors |
| GB2523925B (en) * | 2013-01-02 | 2016-01-20 | Scale Prot As | Scale indication device and method |
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-
2001
- 2001-10-11 US US09/975,161 patent/US6891606B2/en not_active Expired - Lifetime
-
2002
- 2002-02-21 BR BRPI0212913A patent/BRPI0212913B8/en active IP Right Grant
- 2002-02-21 WO PCT/US2002/005160 patent/WO2003031950A1/en not_active Application Discontinuation
- 2002-02-21 EA EA200400522A patent/EA005707B1/en unknown
- 2002-02-21 EP EP02706354A patent/EP1434980B1/en not_active Expired - Lifetime
- 2002-02-21 CA CA2463276A patent/CA2463276C/en not_active Expired - Fee Related
- 2002-02-21 AT AT02706354T patent/ATE489616T1/en not_active IP Right Cessation
- 2002-02-21 MX MXPA04003271A patent/MXPA04003271A/en active IP Right Grant
- 2002-02-21 DE DE60238427T patent/DE60238427D1/en not_active Expired - Lifetime
-
2004
- 2004-04-21 NO NO20041622A patent/NO336313B1/en not_active IP Right Cessation
Also Published As
| Publication number | Publication date |
|---|---|
| EA200400522A1 (en) | 2004-08-26 |
| BR0212913A (en) | 2004-10-13 |
| MXPA04003271A (en) | 2004-07-23 |
| EP1434980A1 (en) | 2004-07-07 |
| EP1434980B1 (en) | 2010-11-24 |
| CA2463276C (en) | 2010-10-19 |
| DE60238427D1 (en) | 2011-01-05 |
| US6891606B2 (en) | 2005-05-10 |
| NO336313B1 (en) | 2015-07-27 |
| ATE489616T1 (en) | 2010-12-15 |
| WO2003031950A1 (en) | 2003-04-17 |
| EA005707B1 (en) | 2005-04-28 |
| US20030071988A1 (en) | 2003-04-17 |
| BRPI0212913B8 (en) | 2016-09-13 |
| NO20041622L (en) | 2004-04-21 |
| BRPI0212913B1 (en) | 2015-03-31 |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| EEER | Examination request | ||
| MKLA | Lapsed |
Effective date: 20130221 |