Smart solids control system

Patent metadata

Field	Value
Publication number	US-12403483-B2
Application number	US-202016931242-A
Country	US
Kind code	B2
Filing date	Jul 16, 2020
Priority date	Jul 16, 2019
Publication date	Sep 2, 2025
Grant date	Sep 2, 2025

Abstract

A material separation system is disclosed that may include a vibratory shaker, a centrifuge, a sensor, and/or a processor circuit. The vibratory shaker may be configured to separate a solid-liquid mixture into a first solids-containing component and a shaker effluent. The sensor may be configured to measure a property of one or more of the solid-liquid mixture, the first solids-containing component, the shaker effluent, and the second solids-containing. A well-performance analysis system may be configured to analyze mud reports of drilling rigs within a geographic basin to determine which rigs are performing inefficiently. The system may allow recommendations and send control signals to improve the efficiency of the solid-liquid separation system. The system may allow an operator to view agglomerated well performance data to identify which rigs are performing below a geographic basin baseline and make informed decisions to improve the functioning of a solid-liquid separation system associated with one or more drilling rigs.

First claim

What is claimed is:

1. A computer-controlled method for operating a solid-liquid separation system for a target well drilling site, the solid-liquid separation system including at least one vibratory screening machine that receives cuttings and well drilling fluid removed from a well at the target well drilling site and that separates the cuttings from the well drilling fluid, the method comprising:
obtaining historical solid-liquid separation system data for a plurality of well drilling sites, the data including, for each well drilling site, settings at which vibratory screening machines operated, an amount of cuttings and well drilling fluid that was removed from the well during well drilling operations and that was processed by the solid-liquid separation system per unit of time, an amount of well drilling fluid that was added during drilling operations per unit of time and an amount of waste solids that were removed and discarded during well drilling operations per unit of time;
conducting a financial analysis of the obtained historical solid-liquid separation system data to identify the well drilling site that provided the lowest operating costs for the solid-liquid separation system per unit of volume of cuttings and well drilling fluid processed by the solid-liquid separation system;
establishing the settings at which the vibratory screening machines operated at the well drilling site that was identified as providing the lowest operating costs as target vibratory screening machine settings;
causing one or more adjustments to be made to the settings of the at least one vibratory screening machine at the target well drilling site until the settings of the at least one vibratory screening machine approximate the target vibratory screening machine settings.

2. The method of claim 1 , wherein the obtaining step comprises obtaining historical solid-liquid separation system data for a plurality of well drilling sites that are within the same geographic basin as the target well drilling site.

3. The method of claim 1 , wherein the obtaining step comprises obtaining historical solid-liquid separation system data for a plurality of well drilling sites that are of the same well type as the target well drilling site.

4. The method of claim 1 , wherein the obtaining step comprises obtaining historical solid-liquid separation system data for a plurality of well drilling sites that are operated by the same operator as the operator of the target well drilling site.

5. The method of claim 1 , wherein the obtaining step comprises obtaining historical solid-liquid separation system data for a plurality of well drilling sites that are operated by one or more operators that are different from the operator of the target well drilling site.

6. The method of claim 1 , wherein settings at which vibratory screening machines are operated within the historical solid-liquid separation system data includes one or more settings in the group consisting of screen angle, shape of vibratory motion, amplitude of vibratory motion, frequency of vibratory motion, screen aperture size and flow rate of cuttings and well drilling fluid being processed per unit of time.

7. The method of claim 1 , wherein causing adjustments to be made to the settings of the at least one vibratory screening machine at the target well drilling site comprises causing an adjustment to be made to the screen angle of the at least one vibratory screening machine.

8. The method of claim 1 , wherein causing adjustments to be made to the settings of the at least one vibratory screening machine at the target well drilling site comprises causing an adjustment to be made to a shape of vibratory motion of the at least one vibratory screening machine.

9. The method of claim 1 , wherein causing adjustments to be made to the settings of the at least one vibratory screening machine at the target well drilling site comprises causing an adjustment to be made to an amplitude of vibratory motion of the at least one vibratory screening machine.

10. The method of claim 1 , wherein causing adjustments to be made to the settings of the at least one vibratory screening machine at the target well drilling site comprises causing an adjustment to be made to a frequency of vibratory motion of the at least one vibratory screening machine.

11. The method of claim 1 , wherein causing adjustments to be made to the settings of the at least one vibratory screening machine at the target well drilling site comprises causing an adjustment to be made to a screen aperture size of the at least one vibratory screening machine.

12. The method of claim 1 , wherein causing adjustments to be made to the settings of the at least one vibratory screening machine at the target well drilling site comprises causing an adjustment to be made to a flow rate of cuttings and drilling fluid per unit of time being processed by the at least one vibratory screening machine.

13. The method of claim 1 , wherein the obtained historical solid-liquid separation system data includes, for each well drilling site, one or more physical characteristics of the solids components that result after cuttings and well drilling fluid has been processed by vibratory screening machines of the solid-liquid separation system at the well drilling site.

14. The method of claim 13 , wherein the establishing step comprises establishing the one or more physical characteristics of the solids component that result after cuttings and well drilling fluid have been processed by vibratory screening machines of the solid-liquid separation system of the well drilling site that was identified as providing the lowest operating costs as part of the target vibratory screening machine settings.

15. The method of claim 14 , wherein the causing step comprises causing adjustments to be made to the settings of the at least one vibratory screening machine at the target well drilling site until the one or more physical characteristics of the solids component that result after cuttings and well drilling fluid have been processed by the at least one vibratory screening machines at the target well drilling site approximate the target vibratory screening machine settings.

16. The method of claim 15 , wherein the one or more physical characteristics of the solids component that result after cuttings and well drilling fluid have been processed by a vibratory screening machine comprises a moisture content of the solids component.

17. The method of claim 15 , wherein the one or more physical characteristics of the solids component that result after cuttings and well drilling fluid have been processed by a vibratory screening machine comprises a density of the solids component.

18. The method of claim 15 , wherein the one or more physical characteristics of the solids component that result after cuttings and well drilling fluid have been processed by a vibratory screening machine comprises a rheology of the solids component.

Assignees

• Derrick Corp

Inventors

• Birchfield Robert Charles Mason
• Stocker Charles
• Derrick Mitchell J
• Rooney Brian J
• Schwec Michael J
• Newman Christian
• Kirsch Raymond

Classifications

• E21B2200/22

  Fuzzy logic, artificial intelligence, neural networks or the like · CPC title

• B01D2201/54

  Computerised or programmable systems · CPC title

• E21B21/065

  Separating solids from drilling fluids · CPC title

• B01D36/045

  Combination of filters with centrifugal separation devices · CPC title

• B01D21/30

  Control equipment · CPC title