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1. (WO2007008793) MULTIPHASE FLUID CHARACTERIZATION
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CLAIMS
What is claimed is:
1. A method for determining a first phase fraction of a multiphase fluid, comprising the actions of:
a) collecting a plurality of measurements on at least a gravitationally- separated portion of the fluid, and identifying at least one said measurement as corresponding to a second phase of the fluid; b) exploiting said identified measurement to correct the values of other ones of said plurality of measurements; and
c) calculating and outputting the fraction of said first phase of the multiphase fluid using at least some of said corrected values of said plurality of measurements.

2. The method of Claim 1 wherein the multiphase fluid is crude petroleum oil, the first phase is a water-continuous phase, and the second phase is an oil-continuous phase.

3. The method of Claim 1 wherein said plurality of measurements include the densities of an oily multiphase fluid and water percentages of the same oily multiphase fluid; wherein said identified measurement is the dry oil density; wherein water percentages of the multiphase fluid by the permittivity method are corrected; wherein flow-weighted water percentages of the multiphase fluid by the density method are calculated; and wherein a flow-weighted average of said corrected water percentages by the permittivity method is used to calculate the water fraction in the crude petroleum oil.

4. The method of Claim 1, wherein said measurements include electrical properties measured by a microwave oscillator load pull device.

5. The method of Claim 1, further comprising the additional step of filtering said measurements.

6. The method of Claim 1, wherein said step of determining correct fluid properties is additionally based on stored data that has been obtained by means other than by means of Claim 1.

7. The method of Claim 1, wherein said measurements are at least partly determined from calculations.

8. The method of Claim 1 wherein the multiphase fluid is a gravitationally-separated crude petroleum oil that will be, has been, or is being transferred from one point to another, and a time series of said plurality of measurements is collected during the transfer.

9. The method of Claim 8, wherein points in said time series are not equally spaced.

10. The method of Claim 8, further comprising the additional step of decimating said time series.

11. A method for making and validating a determination of the aqueous fraction of an oily multiphase fluid, comprising the actions of:
a) collecting a series of density and electrical property measurements across multiple samples of at least a gravitationally-separated oily portion of the fluid;
b) identifying the density of the oily component of the fluid;
c) exploiting said identified density to correct at least some of said electrical property measurements, and making a first determination of the aqueous fraction therewith;
d) using ones of said corrected electrical property measurements to calculate the aqueous phase density, and making a second determination therewith; and
e) generating and outputting a confirmation of a validation if said determinations are adequately matched.

12. The method of Claim 11, wherein said measurements include electrical properties measured by a microwave oscillator load pull device.

13. The method of Claim 11, further comprising the additional step of filtering said measurements.

14. The method of Claim 11, wherein said step of determining correct fluid properties is additionally based on stored data that has been obtained by means other than by means of Claim 11.

15. The method, of Claim 11, wherein said measurements are at least partly determined from calculations.

16. The method of Claim 11 wherein the crude petroleum oil is a particular lot of crude petroleum oil that will be, has been, or is being transferred from one point to another, and a time series of said plurality of measurements is collected during the transfer.

17. The method of Claim 16, wherein points in said time series are not equally spaced.

18. The method of Claim 16, further comprising the additional step of decimating said time series.

19. A multiphase fluid characterization system, comprising:
a densitometer which measures the density of an oily and aqueous multiphase fluid flow stream sourced from a gravitationally-separated multiphase fluid;
an electrical characterization stage which makes one or more electrical property measurements of the flow stream; and
a logic circuit which collects a time series of measurements from said densitometer and said electrical characterization stage, identifies the density of the oily component of the fluid, uses said identified density to correct at least some of said electrical property measurements, makes a first determination of the aqueous fraction, uses ones of said corrected electrical property measurements to calculate the aqueous phase density, make a second determination of said aqueous fraction, and generates and outputs a confirmation of a validation if said determinations are adequately matched.

20. The system of Claim 19, wherein said electrical property measurements include electrical properties measured by a microwave oscillator load pull device.

21. The system of Claim 19, wherein said logic circuit also filters said measurements in the logic circuit.

22. The system of Claim 19, wherein said logic circuit also determines correct fluid properties based additionally on stored data in said circuit that has been obtained by means other than by means of Claim 19.

23. The system of Claim 19, wherein said logic circuit also partly calculates said measurements.

24. The system of Claim 19, wherein said time series in said logic circuit are not equally spaced.

25. The system of Claim 19, wherein said logic circuit also decimates said time series.