Determining wellbore fluid properties

Patent metadata

Field	Value
Publication number	US-9410877-B2
Application number	US-201213650943-A
Country	US
Kind code	B2
Filing date	Oct 12, 2012
Priority date	Oct 12, 2012
Publication date	Aug 9, 2016
Grant date	Aug 9, 2016

Abstract

Computer-implemented methods, software, and systems for determining a property of a wellbore fluid are disclosed. In some implementations, a computing system receives an image of a first sample of the wellbore fluid filling a conduit to a threshold volume of the conduit. The computing system determines a first time duration of the first sample of the wellbore fluid filling the conduit to the threshold volume of the conduit based on the image of the first sample. The computing system receives an image of a second sample of the wellbore fluid filling the conduit to the threshold volume of the conduit. The computing system determines a second time duration of the second sample of the wellbore fluid filling the conduit to the threshold volume of the conduit based on the image of the second sample. A property of the wellbore fluid is determined based on a difference between the first and second time durations.

First claim

What is claimed is:

1. A computer-implemented method of determining a property of a wellbore fluid, the method comprising:
receiving, at a computing system, one or more images of a wellbore fluid sample that at least partially fills a vertically-oriented conduit;
determining, with the computing system, a steady-state level of the wellbore fluid sample within the conduit based on the one or more images;
determining, with the computing system, a time duration to fill the conduit with the wellbore fluid sample to the steady-state level based on the one or more images; and
determining, with the computing system, the property of the wellbore fluid based at least in part on the steady-state level and the time duration;
where the property comprises a viscosity of the wellbore fluid determined at least in part on a density of the wellbore fluid and a dimension of the conduit based on the equation:
μ=[(ρ× g×r 2 ×t )/8]×[( h ss −h ( t )/ h 2 ( t ))];

where μ is the viscosity, ρ is a density of the wellbore fluid, g is gravitational acceleration, h is a height of the conduit, r is a radius of the conduit, t is the time duration, h ss is the steady state level, and h(t) is a height of the wellbore fluid as a function of the time.

2. The method of claim 1 , where the wellbore fluid comprises one of a fracturing fluid, drilling fluid, completion fluid, or formation stimulation fluid.

3. The method of claim 1 , where the conduit comprises a capillary tube.

4. The method of claim 1 , where the computing system comprises a smart phone or a tablet computing device and the steps of receiving and determining are performed at a wellsite, the method further comprising capturing the one or more images of the wellbore fluid sample with the smart phone or tablet computing device at the wellsite.

5. The method of claim 1 , further comprising preparing a visual representation of the property of the wellbore fluid to be displayed on a graphical user interface of the computing system.

6. The method of claim 1 , where the wellbore fluid is a non-Newtonian fluid.

7. A computer program product for determining a property of a wellbore fluid, the computer program product comprising computer readable instructions embodied on tangible media that are operable when executed to perform operations comprising:
receiving one or more images of a wellbore fluid sample that at least partially fills a vertically-oriented conduit;
determining a steady-state level of the wellbore fluid sample within the conduit based on the one or more images;
determining a time duration to fill the conduit with the wellbore fluid sample to the steady-state level based on the one or more images; and
determining the property of the wellbore fluid based at least in part on the steady-state level and the time duration
where the property comprises a viscosity of the wellbore fluid determined at least in part on a density of the wellbore fluid and a dimension of the conduit based on the equation:
μ=[(ρ× g×r 2 ×t )/8]×[( h ss −h ( t )/ h 2 ( t ))];

where μ is the viscosity, ρ is a density of the wellbore fluid, g is gravitational acceleration, h is a height of the conduit, r is a radius of the conduit, t is the time duration, h ss is the steady state level, and h(t) is a height of the wellbore fluid as a function of the time.

8. The computer program product of claim 7 , where the wellbore fluid is a fracturing fluid.

9. The computer program product of claim 7 , where the conduit is a capillary tube.

10. The computer program product of claim 7 , where the operations of receiving and determining are performed at a wellsite with a smart phone or tablet computing device.

11. The computer program product of claim 10 , where the operations further comprise preparing a visual representation of the property of the wellbore fluid to be displayed on a graphical user interface of the smart phone or tablet computing device.

Assignees

• Halliburton Energy Services Inc

Inventors

• Maxey Jason Eric
• Ye Xiangnan
• Chung Hsinchen
• Tonmukayakul Narongsak

Classifications

• G01N33/2823

  Raw oil, drilling fluid or polyphasic mixtures · CPC title

• G01N2291/02818

  Density, viscosity · CPC title

• G01N9/32

  by using flow properties of fluids, e.g. flow through tubes or apertures · CPC title

• G06T2207/30108

  Industrial image inspection · CPC title

• G01N11/04 Primary

  through a restricted passage, e.g. tube, aperture · CPC title