Predicting properties of well bore treatment fluids

Patent metadata

Field	Value
Publication number	US-9657218-B2
Application number	US-201313945136-A
Country	US
Kind code	B2
Filing date	Jul 18, 2013
Priority date	Jul 18, 2013
Publication date	May 23, 2017
Grant date	May 23, 2017

Abstract

Methods and systems for predicting properties of well bore treatment fluids are disclosed. An embodiment includes a method of predicting fluid properties comprising: determining an operational window for a well bore fluid system; collecting data at vertices of the operational window; and developing a model comprising predicted properties for a plurality of data points within the operational window, wherein developing the model uses Barycentric interpolation.

First claim

What is claimed is:

1. A method of predicting fluid properties comprising:
determining an operational window for a well bore fluid system, wherein three or more vertices are selected that define boundary conditions for the well bore fluid system, wherein the boundary conditions comprise a mass ratio of a weighting additive to water and a mass ratio of a viscosifier to water;
dividing the operational window into sub-windows;
conducting a lab test to collect data at the three or more vertices of the operational window; and
developing a model with a computer system, wherein the model is based at least in part on the data, wherein the model comprises predicted properties for a plurality of data points within the operational window, wherein developing the model uses Barycentric interpolation;
selecting a wellbore treatment fluid based on the model; and
introducing the wellbore treatment fluid into a wellbore.

2. The method of claim 1 , wherein determining the operational window comprises two or more boundary conditions for the well bore fluid system.

3. The method of claim 1 , wherein the operational window comprises a triangular, two-dimensional window.

4. The method of claim 1 , wherein the operational window is defined as follows: Vertex 1 (x 1 , y 1 ), Vertex 2 (x 2 , y 2 ), and Vertex 3 (x 3 , y 3 ), wherein x is a first boundary condition for the well bore fluid system and y is a second boundary condition for the well bore fluid system.

5. The method of claim 1 , wherein the collected data includes data selected from the group consisting of rheology, compressive strength, fluid loss, static gel strength, sedimentation, thickening time, free water, Young's modulus, Poisson's ratio, specific heat, thermal conductivity, post-set expansion, wettability, emulsion, break time, pH, post-set permeability, hydration time, post-set porosity, and combinations thereof.

6. The method of claim 1 , further comprising determining density of each of the plurality of data points within the operational window with the computer system.

7. The method of claim 1 , wherein selecting the well bore treatment fluid comprising inputting one or more properties for the well bore treatment fluid, comparing the one or more properties to the predicted properties model; and outputting one or more data points from the model with the computer system.

8. The method of claim 1 , wherein the well bore fluid system comprises a well bore spacer fluid system.

9. A method of predicting fluid properties comprising:
determining an operational window for a well bore fluid system, wherein three or more vertices are selected that define boundary conditions for the well bore fluid system, wherein the boundary conditions comprise a mass ratio of a weighting additive to water and a mass ratio of a viscosifier to water;
dividing the operational window into two or more sub-windows;
collecting data at the three or more vertices of each of the two or more sub-windows using laboratory techniques;
developing a model comprising predicted properties for a plurality of data points within the operational window, wherein developing the model uses Barycentric interpolation, wherein the predicted properties comprise density;
selecting a well bore treatment fluid using the model, wherein selecting the well bore treatment fluid comprises inputting properties of the well bore treatment fluid;
refining the wellbore treatment fluid using simulation and/or laboratory testing; and
introducing the refined wellbore treatment fluid into a wellbore.

10. The method of claim 9 , wherein the operational window comprises a triangular, two-dimensional window.

11. The method of claim 9 , wherein the operational window is defined as follows: Vertex 1 (x 1 , y 1 ), Vertex 2 (x 2 , y 2 ), and Vertex 3 (x 3 , y 3 ), wherein x is a first boundary condition for the well bore fluid system and y is a second boundary condition for the well bore fluid system.

12. The method of claim 9 , wherein the collected data includes data selected from the group consisting of rheology, compressive strength, fluid loss, static gel strength, sedimentation, thickening time, free water, Young's modulus, Poisson's ratio, specific heat, thermal conductivity, post-set expansion, wettability, emulsion, break time, pH, post-set permeability, hydration time, post-set porosity, and combinations thereof.

13. The method of claim 9 , further comprising determining density of each of the plurality of data points within the operational window with the computer system.

14. The method of claim 9 , wherein the well bore fluid system comprises a well bore spacer fluid system.

Assignees

• Halliburton Energy Services Inc

Inventors

• Albrighton Lucas D
• Kennedy Herron J

Classifications

• E21B47/003

  Determining well or borehole volumes · CPC title

• E21B47/047

  Liquid level (measuring depth or liquid level using radioactive markers E21B47/053) · CPC title

• E21B49/0875

  determining specific fluid parameters · CPC title

• C09K8/02 Primary

  Well-drilling compositions · CPC title

• C09K8/424

  using "spacer" compositions · CPC title