XRF measurements of multiphase oilfield fluids

Patent metadata

Field	Value
Publication number	US-12436123-B2
Application number	US-202318461557-A
Country	US
Kind code	B2
Filing date	Sep 6, 2023
Priority date	Sep 6, 2023
Publication date	Oct 7, 2025
Grant date	Oct 7, 2025

Abstract

A method for estimating an elemental composition of a multiphase oilfield fluid includes obtaining a sample of a multiphase oilfield fluid; blending the sample with a viscosity modifying agent to transform the sample into a high viscosity paste; introducing the high viscosity paste into a chamber of an XRF apparatus; using the XRF apparatus to make an XRF measurement of the high viscosity paste; and evaluating the XRF measurement to estimate an elemental composition of the obtained multiphase oilfield fluid.

First claim

What is claimed is:

1. A method for estimating an elemental composition of a multiphase oilfield fluid, the method comprising:
obtaining a sample of the multiphase oilfield fluid;
blending the sample with a viscosity modifying agent to transform the sample into a higher viscosity paste;
introducing the higher viscosity paste into a chamber of an x-ray fluorescence (XRF) apparatus;
using the XRF apparatus to make an XRF measurement of the higher viscosity paste; and
evaluating the XRF measurement to estimate an elemental composition of the obtained multiphase oilfield fluid.

2. The method of claim 1 , wherein the obtained sample comprises a sample of drilling fluid used in a wellbore drilling operation.

3. The method of claim 2 , further comprising adjusting an actual composition of drilling fluid in a mud pit in response to the estimated elemental composition.

4. The method of claim 1 , wherein the viscosity modifying agent comprises carbon black.

5. The method of claim 1 , wherein:
the sample of the multiphase oilfield fluid is automatically obtained from a flow line, a mud pit, or a tank;
the obtained sample is automatically blended with the viscosity modifying agent to transform the obtained sample into the higher viscosity paste; and
the higher viscosity paste is automatically dispensed into a sample cup and transferred to the chamber of the XRF apparatus for making the XRF measurement.

6. The method of claim 1 , wherein the evaluating the XRF measurement further comprises:
developing a correlation between a peak height or an area under a peak in the XRF measurement and a concentration of an element in the multiphase oilfield fluid; and
evaluating the peak height or the area under a peak in the XRF measurement with the correlation to estimate the elemental composition of the multiphase oilfield fluid.

7. The method of claim 1 , wherein:
the multiphase oilfield fluid is a dewatering fluid obtained from a high gravity solids (HGS) recovery system in a drilling fluid dewatering process; and
the evaluating the XRF measurement further comprises evaluating the XRF measurement for at least one of barium, manganese, iron, or calcium to estimate an amount of HGS in the dewatering fluid.

8. The method of claim 7 , further comprising adjusting an operational parameter of the HGS recovery system in response to the estimated amount of HGS in the dewatering fluid.

9. The method of claim 1 , wherein:
the multiphase oilfield fluid is a clean centrate fluid obtained from a low gravity solids (LGS) removal system in a drilling fluid dewatering process; and
the evaluating the XRF measurement further comprises evaluating the XRF measurement for at least one of calcium, magnesium, silicon, aluminum, thorium, or uranium to estimate an amount of LGS in the clean centrate fluid.

10. The method of claim 9 , further comprising adjusting an operational parameter of the LGS removal system in response to the estimated amount of LGS in the clean centrate fluid.

11. A system for estimating an elemental composition of a multiphase oilfield fluid, the system comprising:
a fluid input port configured for receiving a sample of the multiphase oilfield fluid;
a mixer configured to mix the received sample with carbon black to transform the received sample to a higher viscosity paste;
an x-ray fluorescence (XRF) sample holder configured to receive the higher viscosity paste;
an XRF measurement tool configured to make an XRF measurement of the high viscosity paste; and
a processor configured to evaluate the XRF measurement to estimate an elemental composition of the multiphase oilfield fluid.

12. The system of claim 11 , further comprising a carbon black containing vessel configured to transfer the carbon black to the mixer.

13. The system of claim 11 , further comprising:
a paste dispenser configured to transfer the higher viscosity paste to the sample holder; and
a carrousel including a plurality of the sample holders.

14. The apparatus of claim 13 , wherein:
the mixer is configured to automatically receive the sample of the multiphase oilfield fluid and the carbon black and to automatically blend the received sample and the received carbon black to transform the received sample into the higher viscosity paste; and
the paste dispenser is configured to automatically transfer the higher viscosity paste to the sample holder.

15. The system of claim 11 , wherein:
the processor comprises a correlation between a peak height or an area under a peak in the XRF measurement and a concentration of an element in the multiphase oilfield fluid; and
the processor is further configured to evaluate the peak height or the area under a peak in the XRF measurement with the correlation to estimate the elemental composition of the multiphase oilfield fluid.

16. A method for evaluating a multiphase dewatering fluid, the method comprising:
obtaining a sample of the multiphase dewatering fluid from a high gravity solids (HGS) recovery system or a low gravity solids (LGS) removal system in a dewatering process;
blending the obtained sample with carbon black to transform the obtained sample into a paste; and
making an XRF measurement of the paste to estimate an elemental composition of the dewatering fluid.

17. The method of claim 16 , wherein:
the multiphase dewatering fluid is obtained from the HGS recovery system; and
the making the XRF measurement further comprises evaluating the XRF measurement for at least one of barium, manganese, iron, or calcium to estimate an amount of HGS in the multiphase dewatering fluid.

18. The method of claim 17 , further comprising adjusting an operational parameter of a centrifuge in the HGS recovery system in response to the estimated amount of HGS in the dewatering fluid.

19. The method of claim 16 , wherein:
the multiphase dewatering fluid is obtained from the LGS removal system; and
the making the XRF measurement further comprises evaluating the XRF measurement for at least one of calcium, magnesium, silicon, aluminum, thorium, or uranium to estimate an amount of LGS in the multiphase dewatering fluid.

20. The method of claim 19 , further comprising adjusting an operational parameter of a centrifuge in the LGS removal system in response to the estimated amount of LGS in the multiphase dewatering fluid.

Assignees

• Schlumberger Technology Corp

Inventors

• Karoum Reda
• Abad Carlos

Classifications

• G01N35/10

  Devices for transferring samples {or any liquids} to, in, or from, the analysis apparatus, e.g. suction devices, injection devices {(G01N35/0099 takes precedence)} · CPC title

• G01N33/2823 Primary

  Raw oil, drilling fluid or polyphasic mixtures · CPC title

• G01N2035/00465

  Separating and mixing arrangements · CPC title

• G01N23/223 Primary

  by irradiating the sample with X-rays or gamma-rays and by measuring X-ray fluorescence · CPC title

• G01N2223/635

  fluids, granulates · CPC title