Slurry design process

Patent metadata

Field	Value
Publication number	US-11834604-B2
Application number	US-202217720045-A
Country	US
Kind code	B2
Filing date	Apr 13, 2022
Priority date	Feb 22, 2017
Publication date	Dec 5, 2023
Grant date	Dec 5, 2023

Abstract

Methods of wellbore cementing are provided. A method of generating a wellbore treatment fluid may include: classifying a plurality of solid particulates using correlations; calculating a reactive index and/or a water requirement for at least one of the solid particulates; and selecting two or more solid particulates from the plurality of solid particulates to create a wellbore treatment fluid.

First claim

What is claimed is:

1. A method of improving a wellbore treatment fluid, the method comprising:
providing a wellbore treatment fluid comprising one or more solid particulate and a physical property comprising at least a reactive index and a water requirement for each of the one or more solid particulate:
selecting a target value of a mechanical property for the wellbore treatment fluid;
measuring a value of a mechanical property of the wellbore treatment fluid and selecting using a correlation, a second concentration of one or more solid particulate in the wellbore treatment fluid such that a second wellbore treatment fluid comprising the second concentration of the one or more solid particulates meets or exceeds the target value of the mechanical property, wherein the correlation comprises a correlation of a mechanical property of the wellbore treatment fluid to at least reactive index for each of the one or more solid particulate and water requirement for each of the one or more solid particulate; and
preparing the second wellbore treatment fluid.

2. The method of claim 1 , wherein the wellbore treatment fluid further comprises at least one additive selected from the group consisting of weighting agents, retarders, accelerators, activators, gas control additives, lightweight additives, gas-generating additives, mechanical-property-enhancing additives, lost-circulation materials, filtration-control additives, fluid-loss-control additives, defoaming agents, foaming agents, transition time modifiers, dispersants, thixotropic additives, suspending agents, and combinations thereof.

3. The method of claim 1 , wherein the method further comprises allowing an adjusted wellbore treatment fluid to react in a wellbore to form a reacted adjusted treatment fluid.

4. The method of claim 3 , wherein a measured property of the reacted adjusted treatment fluid is nearer to the target property as compared to a measured property of the original wellbore treatment fluid if the original treatment fluid were allowed to react without first adjusting the one or more concentrations of the solid particulates.

5. The method of claim 1 , wherein the adjusting of the one or more concentrations of a solid particulate in the wellbore treatment fluid comprises altering one or more virtual concentrations of a solid particulate in a virtual wellbore treatment fluid.

6. The method of claim 5 , wherein the adjusting additionally comprises altering one or more physical concentrations of one or more solid particulates in a physical wellbore treatment fluid, wherein the altering of the one or more physical concentrations is based on the altering of the one or more virtual concentrations.

7. The method of claim 6 , wherein the altering of the one or more physical concentrations comprises adding a dry blend of two or more components to the physical wellbore treatment fluid.

8. The method of claim 6 , wherein the altering of the one or more physical concentrations comprises adding a blend of two or more components to form a slurry and adding the slurry to the physical wellbore treatment fluid.

9. The method of claim 5 , wherein the solid particulate comprises at least one cement selected from the group consisting of hydraulic cement, cement kiln dust, a natural pozzolan, or a combination thereof.

10. The method of claim 5 , wherein the solid particulate comprises fly ash.

11. The method of claim 5 , wherein the solid particulate comprises a blend of two or more solid components.

12. The method of claim 1 , further comprising:
measuring at least a reactive index and a water requirement for each of a plurality of solid particulates;
preparing a plurality of test wellbore treatment fluids wherein the plurality of test wellbore treatment fluids comprises at least one solid particulate from the plurality of solid particulates;
measuring a mechanical property of each of the plurality of test wellbore treatment fluids;
generating a correlation between the measured physical property of the plurality of solid particulates and the measured mechanical property of each of the plurality of test wellbore treatment fluids.

13. The method of claim 12 , further comprising analyzing the solid particulates to generate data about physical and chemical properties of the solid particulates and generating correlations between the solid particulates based on the data.

14. The method of claim 13 , wherein the analyzing the solid particulates comprises analysis by one or more techniques selected from the group consisting of microscopy, spectroscopy, x-ray diffraction, x-ray fluorescence, particle size analysis, water requirement analysis, scanning electron microscopy, energy-dispersive X-ray spectroscopy, surface area, specific gravity analysis, thermogravimetric analysis, morphology analysis, infrared spectroscopy, ultraviolet-visible spectroscopy, mass spectroscopy, secondary ion mass spectrometry, electron energy mass spectrometry, dispersive x-ray spectroscopy, auger electron spectroscopy, inductively coupled plasma analysis, thermal ionization mass spectroscopy, glow discharge mass spectroscopy x-ray photoelectron spectroscopy, mechanical property testing, Young's Modulus testing, rheological properties, Poisson's Ratio, API testing, and combinations thereof.

15. The method of claim 12 , further comprising generating a statistical table comprising two or more different parameters of the solid particulates.

16. The method of claim 15 , wherein the different parameters comprise the water requirement and the reactive index.

17. The method of claim 12 , further comprising mixing two or more components of the wellbore treatment fluid using mixing equipment to form a mixture, wherein a measured property of the mixture meets or exceeds the target property.

Assignees

• Halliburton Energy Services Inc

Inventors

• Morgan Ronnie Glen
• Pisklak Thomas Jason
• Jimenez Walmy Cuello
• Hundt Gregory Robert
• Benkley James Robert
• Sanders Joseph I
• Singh John P
• Lewis Samuel J

Classifications

• C09K8/467 Primary

  containing additives for specific purposes · CPC title

• C04B40/0032

  Controlling the process of mixing, e.g. adding ingredients in a quantity depending on a measured or desired value (B28C7/00 takes precedence) · CPC title

• C04B2103/10

  Accelerators; Activators · CPC title

• C04B2103/20

  Retarders · CPC title

• C04B2103/46

  Water-loss or fluid-loss reducers, hygroscopic or hydrophilic agents, water retention agents · CPC title