SMART SYSTEM FOR SELECTION OF WELLBORE DRILLING FLUID LOSS CIRCULATION MATERIAL

• US 20190323332A1
• Filed: 04/24/2018
• Published: 10/24/2019
• Est. Priority Date: 04/24/2018
• Status: Active Grant

• Current Assignee: Saudi Arabian Oil Company (Government of Saudi Arabia)
• Original Assignee: Saudi Arabian Oil Company (Government of Saudi Arabia)
• Inventors: Cuellar, Hugo Fernando Osorio, Pino Rojas, Rafael M., Costa de Oliveira, Victor Carlos, Abouelnaaj, Khaled K.
• Granted Patent: US 10,794,170 B2
• Time in Patent Office: Days
• CPC Class Codes: E21B 21/003 Means for stopping loss of drilling fluid plastering the borehole wall E21B33/138
• CPC Class Codes: E21B 21/065 Separating solids from drilling fluids
• CPC Class Codes: E21B 21/08 Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure valve arrangements therefor E21B21/10
• CPC Class Codes: E21B 44/00 Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
• CPC Class Codes: E21B 45/00 Measuring the drilling time or rate of penetration

Abstract

A smart system for circulating LCM can implement a method. While a wellbore is being drilled in a geologic formation, drilling parameters identifying wellbore drilling conditions of a wellbore drilling system drilling the wellbore are received. The wellbore drilling system flows a wellbore drilling fluid including particulates of different size distributions. The particulates operate as LCM to reduce loss of the wellbore drilling fluid in the geologic formation. Size distributions of the particulates in the wellbore drilling fluid flowing through multiple different wellbore fluid flow pathways of the wellbore drilling system are received. The size distributions represent a concentration of the particulates in the wellbore drilling fluid. A release of certain particulates into the wellbore drilling fluid is controlled based, in part, on the received drilling parameters and the received size distributions of the particulates.

Claims

1. A wellbore drilling system comprising:

a plurality of particulate size distribution analyzers, each particulate size distribution analyzer configured to determine a size distribution of particulates in a wellbore drilling fluid circulated through the wellbore drilling system, each particulate size distribution analyzer coupled to a respective wellbore drilling fluid flow pathway, the particulates comprising lost circulation material (LCM) configured to reduce loss of the wellbore drilling fluid into a geologic formation in which the wellbore is being drilled;

a particulates reservoir coupled to the plurality of particulate size distribution analyzers, the particulates reservoir configured to carry particulates of different physical properties, the particulates reservoir configured to release certain particulates into a drilling fluid tank of the wellbore drilling system to be mixed with the wellbore drilling fluid circulated through the drilling fluid tank; and

a processing system coupled to the plurality of particulate size distribution analyzers and to the particulates reservoir, the processing system configured to perform operations while drilling the wellbore, the operations comprising;

receiving drilling parameters identifying wellbore drilling conditions of the wellbore drilling system;

receiving size distributions of particulates in the wellbore drilling fluid from the plurality of particulate size distribution analyzers; and

controlling the particulates reservoir to release the certain particulates into the drilling fluid tank based, in part, on the received drilling parameters and the received size distributions of the particulates.

2. The system of claim 1, wherein the plurality of particulate size distribution analyzers comprises:

a first particulate size distribution analyzer coupled to a first wellbore drilling fluid flow pathway between a drilling fluid pump and a drilling rig;

a second particulate size distribution analyzer coupled to a second wellbore drilling fluid flow pathway between the drilling rig and a shaker system; and

a third particulate size distribution analyzer coupled to a third wellbore drilling fluid flow pathway between the shaker system and the drilling fluid tank.

3. The system of claim 1, wherein the particulates reservoir comprises:

a fine particulates reservoir containing particulates of a first size distribution, the fine particulates reservoir coupled to the drilling fluid tank, the fine particulates reservoir configured to release a quantity of the particulates of the first size distribution into the drilling fluid tank in response to a first controlling signal from the processing system;

a medium particulates reservoir containing particulates of a second size distribution greater than the first size distribution, the medium particulates reservoir coupled to the drilling fluid tank, the medium particulates reservoir configured to release a quantity of the particulates of the second size distribution into the drilling fluid tank in response to a second controlling signal from the processing system; and

a coarse particulates reservoir containing particulates of a third size distribution greater than the second size distribution, the coarse particulates reservoir coupled to the drilling fluid tank, the coarse particulates reservoir configured to release a quantity of the particulates of the third size distribution into the drilling fluid tank in response to a third controlling signal from the processing system.

4. The system of claim 1, wherein each particulate size distribution analyzer is configured to determine the size distribution of particulates in the wellbore drilling fluid circulated through the respective wellbore drilling fluid flow pathway during wellbore drilling.

5. The system of claim 1, wherein the drilling parameters include a rate of penetration of a drill bit, a flow rate of the wellbore drilling fluid through the wellbore, and a rate of loss of the wellbore drilling fluid in the geologic formation in which the wellbore is being drilled.

6. The system of claim 1, wherein a concentration of the particulates in the wellbore drilling fluid decrease during the wellbore drilling operations, wherein the processing system is configured to perform operations comprising:

determining, based on the received drilling parameters and the received size distributions of the particulates, a quantity of the particulates to be added to the wellbore drilling fluid to increase the concentration of the particulates to a level sufficient to reduce the loss of the wellbore drilling fluid into a geologic formation in which the wellbore is being drilled.

7. The system of claim 6, wherein the processing system is configured to perform operations comprising periodically providing, as outputs, concentrations of the particulates in the wellbore drilling fluid during the wellbore drilling operations.

8. The system of claim 1, wherein the different physical properties of the particulates comprise a particulate size ranging between 1 micrometer and 2,000 micrometers.

9. A method comprising:

while a wellbore is being drilled in a geologic formation, receiving drilling parameters identifying wellbore drilling conditions of a wellbore drilling system drilling the wellbore, the wellbore drilling system flowing a wellbore drilling fluid comprising particulates of different size distributions, the particulates operating as lost circulation material (LCM) to reduce loss of the wellbore drilling fluid in the geologic formation;

receiving size distributions of the particulates in the wellbore drilling fluid flowing through a plurality of different wellbore drilling fluid flow pathways of the wellbore drilling system, the size distributions representing a concentration of the particulates in the wellbore drilling fluid; and

controlling a release of certain particulates into the wellbore drilling fluid based, in part, on the received drilling parameters and the received size distributions of the particulates.

10. The method of claim 9, wherein the drilling parameters include a rate of penetration of a drill bit, a flow rate of the wellbore drilling fluid through the wellbore, and a rate of loss of the wellbore drilling fluid in the geologic formation in which the wellbore is being drilled.

11. The method of claim 9, wherein a concentration of the particulates in the wellbore drilling fluid decrease during the wellbore drilling operations, wherein the method further comprises:

determining, based on the received drilling parameters and the received size distributions of the particulates, a quantity of the particulates to be added to the wellbore drilling fluid to increase the concentration of the particulates to a level sufficient to reduce the loss of the wellbore drilling fluid into a geologic formation in which the wellbore is being drilled.

12. The method of claim 10, further comprising periodically providing, as outputs, concentrations of the particulates in the wellbore drilling fluid during the wellbore drilling operations.

13. The method of claim 9, wherein a particulates reservoir carries particulates of different physical properties comprising a particulate size ranging between 1 micrometer and 2,000 micrometers.

14. The method of claim 9, wherein the certain particulates comprise one or more of particulates of a first size distribution, particulates of a second size distribution greater than the first size distribution, and particulates of a third size distribution greater than the second size distribution.

15. A wellbore drilling system comprising:

a drilling fluid tank configured to carry wellbore drilling fluid;

a wellbore pump configured to pump the wellbore drilling fluid during a wellbore drilling operation;

a wellbore drilling rig configured to support wellbore drilling equipment configured to drill the wellbore in a geologic formation during the wellbore drilling operation;

a shaker system configured to remove cuttings carried by the wellbore drilling fluid during the wellbore drilling operation;

a plurality of particulate size distribution analyzers, each particulate size distribution analyzer configured to determine a size distribution of particulates in a wellbore drilling fluid circulated through the wellbore drilling system, each particulate size distribution analyzer coupled to a respective wellbore drilling fluid flow pathway through which the wellbore drilling fluid is flowed, the particulates comprising lost circulation material (LCM) configured to reduce loss of the wellbore drilling fluid into the geologic formation in which the wellbore is being drilled; and

a processing system coupled to the plurality of particulate size distribution analyzers, the processing system configured to perform operations while drilling the wellbore, the operations comprising;

receiving drilling parameters identifying wellbore drilling conditions of the wellbore drilling system;

receiving size distributions of particulates in the wellbore drilling fluid from the plurality of particulate size distribution analyzers; and

releasing the certain particulates into the drilling fluid tank based, in part, on the received drilling parameters and the received size distributions of the particulates.

16. The system of claim 15, wherein the plurality of particulate size distribution analyzers comprises:

a first particulate size distribution analyzer coupled to a first wellbore drilling fluid flow pathway between a drilling fluid pump and a drilling rig;

a second particulate size distribution analyzer coupled to a second wellbore drilling fluid flow pathway between the drilling rig and a shaker system; and

a third particulate size distribution analyzer coupled to a third wellbore drilling fluid flow pathway between the shaker system and the drilling fluid tank.

17. The system of claim 15, wherein the particulates reservoir comprises:

a fine particulates reservoir containing particulates of a first size distribution, the fine particulates reservoir coupled to the drilling fluid tank, the fine particulates reservoir configured to release a quantity of the particulates of the first size distribution into the drilling fluid tank in response to a first controlling signal from the processing system;

a medium particulates reservoir containing particulates of a second size distribution greater than the first size distribution, the medium particulates reservoir coupled to the drilling fluid tank, the medium particulates reservoir configured to release a quantity of the particulates of the second size distribution into the drilling fluid tank in response to a second controlling signal from the processing system; and

a coarse particulates reservoir containing particulates of a third size distribution greater than the second size distribution, the coarse particulates reservoir coupled to the drilling fluid tank, the coarse particulates reservoir configured to release a quantity of the particulates of the third size distribution into the drilling fluid tank in response to a third controlling signal from the processing system.

18. The system of claim 16, wherein each particulate size distribution analyzer is configured to determine the size distribution of particulates in the wellbore drilling fluid circulated through the respective wellbore drilling fluid flow pathway during wellbore drilling.

19. The system of claim 16, wherein the drilling parameters include a rate of penetration of a drill bit, a flow rate of the wellbore drilling fluid through the wellbore, and a rate of loss of the wellbore drilling fluid in the geologic formation in which the wellbore is being drilled.

20. The system of claim 16, wherein a concentration of the particulates in the wellbore drilling fluid decrease during the wellbore drilling operations, wherein the processing system is configured to perform operations comprising determining, based on the received drilling parameters and the received size distributions of the particulates, a quantity of the particulates to be added to the wellbore drilling fluid to increase the concentration of the particulates to a level sufficient to reduce the loss of the wellbore drilling fluid into a geologic formation in which the wellbore is being drilled.