Dynamic formulation of water-based drilling fluids
Drilling fluid can be monitored throughout a drill site and at various stages of drilling operations. The drilling fluid may be analyzed to identify components that make the drilling fluid as well as the volume of each of the components, The volume of each component can be used, for example, to determine a percentage of water in a water-based drilling fluid and the average specific gravity of the water-based drilling fluid without further decomposition of the drilling fluid. The percentage of water and the average specific gravity can then be used to modify the drilling fluid, in real-time, based on conditions in the wellbore.
1. A system comprising
a housing defining a fluid reservoir, the housing including an inlet to receive a water-based drilling fluid that is configured to be pumped into a wellbore, the water-based drilling fluid comprising of brine, a low-gravity solids, and a high-gravity solids;
a fluid analyzer comprising one or more processors and a non-transitory computer-readable medium storing instructions that when executed by the one or more processors cause the fluid analyzer to perform operations including:
receiving a target property value that corresponds to an optimal value of a property of the water-based drilling fluid;
determining a volume of the brine, a volume of the low-gravity solids, and a volume the high-gravity solids that are within the water-based drilling fluid;
calculating, using the volume of the low-gravity solids and the volume of the high-gravity solids, an average specific gravity of the water-based drilling fluid;
determining, using the volume of the brine, a percentage of water that is within the water-based drilling fluid;
calculating, using the average specific gravity and the percentage of water, a value of the property of the water-based drilling fluid; and
controlling a drilling system to reformulate a fluid composition of the water-based drilling fluid using the value of the property of the water-based drilling fluid.
2. The system of claim 1 , wherein determining the volume of the brine, the volume of the low-gravity solids, and the volume the high-gravity solids that are within the water-based drilling fluid includes:
calculating a thermal conductivity for the water-based drilling fluid as a function of the thermal conductivity of each of the brine, the low-gravity solids, and the high-gravity solids.
3. The system of claim 1 , wherein the inlet receives the water-based drilling fluid before the water-based drilling fluid is pumped into the wellbore.
4. The system of claim 1 , wherein the inlet receives the water-based drilling fluid as the water-based drilling fluid exits the wellbore.
5. The system of claim 1 , wherein determining a volume of brine, a volume of low-gravity solids, and a volume high-gravity solids within the water-based drilling fluid includes:
measuring a density of the water-based drilling fluid; and
determining updated values for the volume of the brine in real-time, the volume of the low-gravity solids, and the volume of the high-gravity solids with every density measurement.
6. The system of claim 1 , wherein in the property is a hydrostatic pressure exerted by the water-based drilling fluid within the wellbore, and wherein controlling the drilling system to reformulate the fluid composition of the water-based drilling fluid using the value of the property of the water-based drilling fluid includes:
determining that the hydrostatic pressure is lower than the target property value; and
increasing the volume of the high-gravity solids relative to the brine in the water-based drilling fluid to increase the hydrostatic pressure that is exerted by the water-based drilling fluid such that the hydrostatic pressure that is exerted is approximately equal to the target property value.
7. The system of claim 1 , wherein in the property is a hydrostatic pressure exerted by the water-based drilling fluid within the wellbore, and wherein controlling the drilling system to reformulate the fluid composition of the water-based drilling fluid using the value of the property of the water-based drilling fluid includes:
determining that the hydrostatic pressure exceeds the target property value; and
increasing the volume of the brine relative to the high-gravity solids in the water-based drilling fluid to decrease the hydrostatic pressure that is exerted by the water-based drilling fluid such that the hydrostatic pressure that is exerted is approximately equal to the target property value.
8. A method comprising:
receiving a water-based drilling fluid configured to be pumped into a wellbore during drilling operations, the water-based drilling fluid including brine, a low-gravity solids, and a high-gravity solids;
determining a volume of the brine, a volume of the low-gravity solids, and a volume the high-gravity solids that are within the water-based drilling fluid;
calculating, using the volume of the low-gravity solids and the volume of the high-gravity solids, an average specific gravity of the water-based drilling fluid;
determining, using the volume of the brine, a percentage of water that is within the water-based drilling fluid;
receiving a target property value that corresponds to an optimal value of a property of the water-based drilling fluid;
calculating, using the average specific gravity and the percentage of water, a value of the property of the water-based drilling fluid; and
controlling a drilling system to reformulate a fluid composition of the water-based drilling fluid using the value of the property of the water-based drilling fluid.
9. The method of claim 8 , wherein determining the volume of the brine, the volume of the low-gravity solids, and the volume the high-gravity solids that are within the water-based drilling fluid includes:
calculating a thermal conductivity for the water-based drilling fluid as a function of the thermal conductivity of each of the brine, the low-gravity solids, and the high-gravity solids.
10. The method of claim 8 , wherein the water-based drilling fluid is received prior to the water-based drilling fluid being pumped into the wellbore.
11. The method of claim 8 , wherein the water-based drilling fluid is received as it exits the wellbore.
12. The method of claim 8 , wherein determining the volume of the brine, the volume of the low-gravity solids, and the volume the high-gravity solids within the water-based drilling fluid includes:
measuring a density of each of the brine, the low-gravity solids, and the high-gravity solids every sixty seconds; and
determining updated values for the volume of the brine in real-time, the volume of the low-gravity solids, and the volume the high-gravity solids with every density measurement.
13. The method of claim 8 , wherein in the property is a hydrostatic pressure exerted by the water-based drilling fluid within the wellbore, and wherein controlling the drilling system to reformulate the fluid composition of the water-based drilling fluid using value of the property of the water-based drilling fluid includes:
determining that the hydrostatic pressure is lower than the target property value; and
increasing the volume of the high-gravity solids relative to the brine in the water-based drilling fluid to increase the hydrostatic pressure that is exerted by the water-based drilling fluid such that the hydrostatic pressure that is exerted is approximately equal to the target property value.
14. The method of claim 8 , wherein in the property is a hydrostatic pressure exerted by the water-based drilling fluid within the wellbore, and wherein controlling the drilling system to reformulate the fluid composition of the water-based drilling fluid using the value of the property of the water-based drilling fluid:
determining that the hydrostatic pressure exceeds the target property value; and
increasing the volume of the brine relative to the high-gravity solids in the water-based drilling fluid to decrease the hydrostatic pressure that is exerted by the water-based drilling fluid such that the hydrostatic pressure that is exerted is approximately equal to the target property value.
15. A non-transitory computer-readable medium including instructions that are executable by one or more processors to cause the one or more processors to perform operations including:
receiving a water-based drilling fluid configured to be pumped into a wellbore during drilling operations, the water-based drilling fluid including brine, a low-gravity solids, and a high-gravity solids;
determining a volume of the brine, a volume of the low-gravity solids, and a volume the high-gravity solids that are within the water-based drilling fluid;
calculating, using the volume of the low-gravity solids and the volume of the high-gravity solids, an average specific gravity of the water-based drilling fluid;
determining, using the volume of the brine, a percentage of water that is within the water-based drilling fluid;
receiving a target property value that corresponds to an optimal value of a property of the water-based drilling fluid;
calculating, using the average specific gravity and the percentage of water, a value of the property of the water-based drilling fluid; and
controlling a drilling system to reformulate a fluid composition of the water-based drilling fluid using the value of the property of the water-based drilling fluid.
16. The non-transitory computer-readable medium of claim 15 , wherein determining the volume of the brine, the volume of the low-gravity solids, and the volume the high-gravity solids that are within the water-based drilling fluid includes:
calculating a thermal conductivity for the water-based drilling fluid as a function of the thermal conductivity of each of the brine, the low-gravity solids, and the high-gravity solids.
17. The non-transitory computer-readable medium of claim 15 , wherein the water-based drilling fluid is received as it exits the wellbore.
18. The non-transitory computer-readable medium of claim 15 , wherein determining the volume of the brine, the volume of the low-gravity solids, and the volume of the high-gravity solids within the water-based drilling fluid includes:
measuring a density of each of the brine, the low-gravity solids, and the high-gravity solids every sixty seconds; and
determining updated values for the volume of the brine in real-time, the volume of the low-gravity solids, and the volume of the high-gravity solids with every density measurement.
19. The non-transitory computer-readable medium of claim 15 , wherein in the property is a hydrostatic pressure exerted by the water-based drilling fluid within the wellbore, and wherein controlling the drilling system to reformulate the fluid composition of the water-based drilling fluid using the value of the property of the water-based drilling fluid includes:
determining that the hydrostatic pressure is lower than the target property value; and
increasing the volume of the high-gravity solids relative to the brine in the water-based drilling fluid to increase the hydrostatic pressure that is exerted by the water-based drilling fluid such that the hydrostatic pressure that is exerted is approximately equal to the target property value.
20. The non-transitory computer-readable medium of claim 15 , wherein in the property is a hydrostatic pressure exerted by the water-based drilling fluid within the wellbore, and controlling the drilling system to reformulate the fluid composition of the water-based drilling fluid using the value of the property of the water-based drilling fluid includes:
determining that the hydrostatic pressure exceeds the target property value; and
increasing the volume of the brine relative to the high-gravity solids in the water-based drilling fluid to decrease the hydrostatic pressure that is exerted by the water-based drilling fluid such that the hydrostatic pressure that is exerted is approximately equal to the target property value.