SG10201805383XA - Method and system for multi-phase flow measurement - Google Patents
Method and system for multi-phase flow measurementInfo
- Publication number
- SG10201805383XA SG10201805383XA SG10201805383XA SG10201805383XA SG10201805383XA SG 10201805383X A SG10201805383X A SG 10201805383XA SG 10201805383X A SG10201805383X A SG 10201805383XA SG 10201805383X A SG10201805383X A SG 10201805383XA SG 10201805383X A SG10201805383X A SG 10201805383XA
- Authority
- SG
- Singapore
- Prior art keywords
- temperature profile
- sensing
- location
- phase flow
- sensing location
- Prior art date
Links
- 238000000034 method Methods 0.000 title abstract 3
- 238000005259 measurement Methods 0.000 title abstract 2
- 238000010438 heat treatment Methods 0.000 abstract 2
- 230000000644 propagated effect Effects 0.000 abstract 1
Classifications
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
- G01F1/74—Devices for measuring flow of a fluid or flow of a fluent solid material in suspension in another fluid
-
- 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
- E21B47/06—Measuring temperature or pressure
- E21B47/07—Temperature
-
- 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
- E21B47/13—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 by electromagnetic energy, e.g. radio frequency
- E21B47/135—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 by electromagnetic energy, e.g. radio frequency using light waves, e.g. infrared or ultraviolet waves
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
- G01F1/66—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by measuring frequency, phase shift or propagation time of electromagnetic or other waves, e.g. using ultrasonic flowmeters
- G01F1/662—Constructional details
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
- G01F1/68—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by using thermal effects
- G01F1/684—Structural arrangements; Mounting of elements, e.g. in relation to fluid flow
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01K—MEASURING TEMPERATURE; MEASURING QUANTITY OF HEAT; THERMALLY-SENSITIVE ELEMENTS NOT OTHERWISE PROVIDED FOR
- G01K11/00—Measuring temperature based upon physical or chemical changes not covered by groups G01K3/00, G01K5/00, G01K7/00 or G01K9/00
- G01K11/32—Measuring temperature based upon physical or chemical changes not covered by groups G01K3/00, G01K5/00, G01K7/00 or G01K9/00 using changes in transmittance, scattering or luminescence in optical fibres
- G01K11/3206—Measuring temperature based upon physical or chemical changes not covered by groups G01K3/00, G01K5/00, G01K7/00 or G01K9/00 using changes in transmittance, scattering or luminescence in optical fibres at discrete locations in the fibre, e.g. using Bragg scattering
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
- G01F1/704—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow using marked regions or existing inhomogeneities within the fluid stream, e.g. statistically occurring variations in a fluid parameter
- G01F1/7044—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow using marked regions or existing inhomogeneities within the fluid stream, e.g. statistically occurring variations in a fluid parameter using thermal tracers
Landscapes
- Physics & Mathematics (AREA)
- Engineering & Computer Science (AREA)
- Fluid Mechanics (AREA)
- General Physics & Mathematics (AREA)
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Remote Sensing (AREA)
- Electromagnetism (AREA)
- Environmental & Geological Engineering (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Geophysics (AREA)
- Measuring Temperature Or Quantity Of Heat (AREA)
- Measuring Volume Flow (AREA)
Abstract
METHOD AND SYSTEM FOR MULTI-PHASE FLOW MEASUREMENT Systems and methods for detecting a condition of multi-phase flow through a component with a first sensing cable having a first sensor location and aligned with a heating element and a second sensing cable having a second sensing location a predetermined distance from the first sensing location. A heat pulse is propagated through the heating element. A first temperature profile at the first sensing location and a second temperature profile at the second sensing location, each corresponding to the heat pulse, are measured over time. A flow velocity is determined by correlating the first temperature profile with the second temperature profile. A condition of flow of the media is detected by determining a phase of at least one medium exposed to the sensing cable at the first sensing location based on the first temperature profile and the determined flow velocity. (Fig. 10)
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US201361919870P | 2013-12-23 | 2013-12-23 |
Publications (1)
Publication Number | Publication Date |
---|---|
SG10201805383XA true SG10201805383XA (en) | 2018-08-30 |
Family
ID=50625208
Family Applications (2)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
SG11201506418RA SG11201506418RA (en) | 2013-12-23 | 2014-03-28 | Method and system for multi-phase flow measurement |
SG10201805383XA SG10201805383XA (en) | 2013-12-23 | 2014-03-28 | Method and system for multi-phase flow measurement |
Family Applications Before (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
SG11201506418RA SG11201506418RA (en) | 2013-12-23 | 2014-03-28 | Method and system for multi-phase flow measurement |
Country Status (5)
Country | Link |
---|---|
US (1) | US10634536B2 (en) |
EP (1) | EP3087353A1 (en) |
CA (1) | CA2901852A1 (en) |
SG (2) | SG11201506418RA (en) |
WO (1) | WO2015099818A1 (en) |
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US9746434B2 (en) | 2013-03-28 | 2017-08-29 | Exxonmobil Research And Engineering Company | Method and system for determining flow distribution through a component |
US9778115B2 (en) | 2013-03-28 | 2017-10-03 | Exxonmobil Research And Engineering Company | Method and system for detecting deposits in a vessel |
US9880035B2 (en) | 2013-03-28 | 2018-01-30 | Exxonmobil Research And Engineering Company | Method and system for detecting coking growth and maldistribution in refinery equipment |
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WO2016204724A1 (en) * | 2015-06-15 | 2016-12-22 | Halliburton Energy Services, Inc. | Application of the time derivative of distributed temperature survey (dts) in identifying flows in and around a wellbore during and after hydraulic fracture |
GB2550866B (en) * | 2016-05-26 | 2019-04-17 | Metrol Tech Ltd | Apparatuses and methods for sensing temperature along a wellbore using semiconductor elements |
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CN107940245A (en) * | 2017-11-13 | 2018-04-20 | 中国石油大学(华东) | Gas-liquid stratified flow pipeline leakage positioning method and system based on single-point dual sensor |
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-
2014
- 2014-03-27 US US14/226,948 patent/US10634536B2/en active Active
- 2014-03-28 EP EP14720440.8A patent/EP3087353A1/en not_active Withdrawn
- 2014-03-28 CA CA2901852A patent/CA2901852A1/en not_active Abandoned
- 2014-03-28 SG SG11201506418RA patent/SG11201506418RA/en unknown
- 2014-03-28 WO PCT/US2014/032134 patent/WO2015099818A1/en active Application Filing
- 2014-03-28 SG SG10201805383XA patent/SG10201805383XA/en unknown
Also Published As
Publication number | Publication date |
---|---|
EP3087353A1 (en) | 2016-11-02 |
CA2901852A1 (en) | 2015-07-02 |
US10634536B2 (en) | 2020-04-28 |
SG11201506418RA (en) | 2015-09-29 |
US20150177042A1 (en) | 2015-06-25 |
WO2015099818A1 (en) | 2015-07-02 |
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