Granted Patent B2

US 12,264,565 · App. 18/077,740 · Granted Apr 1, 2025

Inventors: Oswaldo J. Perez (Houston, TX); Francisco E. Fragachan (Katy, TX)

Assignee: Weatherford Technology Holdings, LLC

E21B43/26E21B41/00E21B43/267E21B49/00G01N11/162

Abstract

Claims (107)

1. A method implemented with a wellbore system having a programmable control device and a pump system to perform a wellbore operation in a wellbore in a formation, the method comprising:

obtaining, with the programmable control device, wellbore parameters characterizing the wellbore operation in the wellbore, the wellbore operation requiring use of a target fluid having at least one target parameter of a transport performance, a suspension performance, a characteristic density, a characteristic viscosity, and a friction performance;

obtaining, with the programmable control device, fluid parameters characterizing an elastic fluid for use as the target fluid in the wellbore operation in the wellbore to achieve the at least one target parameter, wherein:

(i) the fluid parameters are defined by regions of elastic behavior for the elastic fluid relating shear rate relative to viscosity of the elastic fluid, the regions of elastic behavior including a viscous region defined by the Power Law and including an elastic region defined by storage modulus (G′) relative to loss modulus (G″), the regions of elastic behavior being calculated from a threshold of the shear rate at which the Power Law applies to the elastic fluid based on: a first differential equation of the viscosity with respect to shear rate:

δ

⁢

μ

δ

⁢

γ

,

 a second differential equation of a flow index (n′) of the Power Law with respect to shear rate:

δ

⁢

n

⁢

′

δ

⁢

γ

,

 and a third differential equation of the storage modulus (G′) with and respect to shear rate:

δ

⁢

G

⁢

′

δ

⁢

γ

.

 and

(ii) the fluid parameters define, according to the regions of elastic behavior, friction behavior of the elastic fluid relating fiction gradient relative to flow rate of the elastic fluid;

determining, with the programmable control device, operational parameters for using the elastic fluid as the target fluid in the wellbore operation in the wellbore to achieve the at least one target parameter by modeling the wellbore operation using the elastic fluid based on the wellbore parameters and the fluid parameters;

preparing a treatment of the elastic fluid having the fluid parameters by adding an elastic fluid agent to a base fluid; and

performing, through an interface of the programmable control device with the pump system, the wellbore operation by pumping the treatment of the elastic fluid in the wellbore with the pump system according to the determined operational parameters to reach the at least one target parameter.

2. The method of claim 1 , wherein the regions of elastic behavior are defined by elastic modules determined by an oscillation test performed on the elastic fluid.

3. The method of claim 1 , wherein the friction behavior of the elastic fluid relating the fiction gradient relative to the flow rate of the elastic fluid is determined in two different friction segments, including a first of the friction segments for the viscous region defined by the Power Law, and a second of the friction segments for the elastic region defined by the storage modulus (G′) relative to the loss modulus (G″).

4. The method of claim 1 , wherein the friction behavior of the elastic fluid relating the fiction gradient relative to the flow rate of the elastic fluid is determined by: friction loop testing of the elastic fluid performed in a plurality of pipe sizes at a plurality of different ones of the flow rates; and a plurality of the friction gradient of the elastic fluid estimated at the different flow rates for the plurality of pipe sizes.

5. The method of claim 1 , wherein the wellbore operation is a hydraulic fracturing operation using the elastic fluid and proppant; and wherein modeling the hydraulic fracturing operation using the elastic fluid based on the wellbore parameters and the fluid parameters comprises optimizing the operational parameters based on a selection of the elastic fluid, a type of the proppant, a concentration of the proppant, and a pumping rate of the elastic fluid and the proppant according to a stimulation objective.

6. The method of claim 1 , wherein the wellbore operation is a hydraulic fracturing operation; and wherein modeling the hydraulic fracturing operation using the elastic fluid based on the wellbore parameters and the fluid parameters comprises modelling based on one or more of: reservoir depth, pore pressure gradient, porosity, permeability, total organic carbon (TOC), water saturation, Young's modulus, Poisson's ratio, rock strength, cohesion, and sh-min gradient.

7. The method of claim 1 , wherein the wellbore operation is a hydraulic fracturing operation using the elastic fluid and proppant; and wherein modeling the hydraulic fracturing operation comprises one or more of:

performing a simulation to predict hydraulic fracture propagation, fracture height growth, and natural fracture reactivation;

performing a simulation to model transport of the proppant within both main hydraulic fractures and a reactivated natural fracture network;

performing a simulation to assess embedment of the proppant and crush-fracture surface closure behavior during production; and

performing a simulation to forecast production efficiency.

8. The method of claim 1 , wherein the wellbore operation is a hydraulic fracturing operation using the elastic fluid and proppant; and wherein performing the hydraulic fracturing operation comprises;

mixing the proppant with the treatment of the elastic fluid; and

pumping the treatment of the elastic fluid mixed with the proppant according to one or more of a pressure with the pump system, a stimulation time with the pump system, a density of the proppant, and a diameter of the proppant from the determined operational parameters.

9. The method of claim 1 , further comprising:

obtaining, with the programmable control device, field data of the elastic fluid by assessing the performance of the wellbore operation; and

updating, with the programmable control device, the fluid parameters of the elastic fluid based on the obtained field data.

10. The method of claim 9 , wherein obtaining the field data comprises collecting friction data at different rates and flow path restrictions; and wherein updating the fluid parameters comprises improving the determination of the friction behavior of the elastic fluid with the collected friction data at the different flow rates and the flow path restrictions.

11. A method implemented with a wellbore system having a programmable control device and a pump system to perform a wellbore operation in a wellbore in a formation, the method comprising:

obtaining, with the programmable control device, wellbore parameters characterizing the wellbore operation in the wellbore, the wellbore operation requiring use of a target fluid having at least one target parameter of a transport performance, a suspension performance, a characteristic density, a characteristic viscosity, and a friction performance;

obtaining, with the programmable control device, fluid parameters characterizing an elastic fluid for use as the target fluid in the wellbore operation in the wellbore to achieve the at least one target parameter, wherein:

(i) the fluid parameters are defined by regions of elastic behavior for the elastic fluid relating shear rate relative to viscosity of the elastic fluid, the regions of elastic behavior including a viscous region defined by the Power Law and including an elastic region defined by storage modulus (G′) relative to loss modulus (G″), and

(ii) the fluid parameters define, according to the regions of elastic behavior, friction behavior of the elastic fluid relating fiction gradient relative to flow rate of the elastic fluid, wherein the friction behavior of the elastic fluid relating the fiction gradient relative to the flow rate of the elastic fluid is determined by: (a) experimental data points in terms of Reynolds number obtained at different shear rate stations in friction flow loop testing, wherein the Reynolds number is measured at each stabilized step; and (b) pressure losses computed with the experimental data at the different shear rate stations to produce a pressure mathematical model that correlates with pressure drop hydraulics;

determining, with the programmable control device, operational parameters for using the elastic fluid as the target fluid in the wellbore operation in the wellbore to achieve the at least one target parameter by modeling the wellbore operation using the elastic fluid based on the wellbore parameters and the fluid parameters;

preparing a treatment of the elastic fluid having the fluid parameters by adding an elastic fluid agent to a base fluid; and

performing, through an interface of the programmable control device with the pump system, the wellbore operation by pumping the treatment of the elastic fluid in the wellbore with the pump system according to the determined operational parameters to reach the at least one target parameter.

12. The method recited in claim 11 , wherein the pressure losses are computed by the experimental data processed in a hydraulics model to find a best curve fit combining the Reynolds number and the shear rate for each of the stations in the region of the elastic behavior of the elastic fluid defined by the storage modulus (G′) being greater than the loss modulus (G″).

13. The method of claim 12 , wherein modeling the wellbore operation using the elastic fluid based on the wellbore parameters and the fluid parameters comprises:

modeling flow restrictions in the wellbore for the wellbore operation; and

calculating the pressure losses of the elastic fluid pumped at a pump rate through the modeled flow restrictions.

14. The method of claim 11 , wherein the friction behavior of the elastic fluid relating the fiction gradient relative to the flow rate of the elastic fluid is at least one of:

determined in two different friction segments, including a first of the friction segments for the viscous region defined by the Power Law, and a second of the friction segments for the elastic region defined by the storage modulus (G′) relative to the loss modulus (G″); and

determined by: friction loop testing of the elastic fluid performed in a plurality of pipe sizes at a plurality of different ones of the flow rates; and a plurality of the friction gradient of the elastic fluid estimated at the different flow rates for the plurality of pipe sizes.

15. The method of claim 11 , wherein the wellbore operation is a hydraulic fracturing operation using the elastic fluid and proppant; and wherein modeling the hydraulic fracturing operation using the elastic fluid based on the wellbore parameters and the fluid parameters comprises one or more of:

optimizing the operational parameters based on a selection of the elastic fluid, a type of the proppant, a concentration of the proppant, and a pumping rate of the elastic fluid and the proppant according to a stimulation objective;

modelling based on one or more of: reservoir depth, pore pressure gradient, porosity, permeability, total organic carbon (TOC), water saturation, Young's modulus, Poisson's ratio, rock strength, cohesion, and sh-min gradient;

performing a simulation to predict hydraulic fracture propagation, fracture height growth, and natural fracture reactivation;

performing a simulation to model transport of the proppant within both main hydraulic fractures and a reactivated natural fracture network;

performing a simulation to assess embedment of the proppant and crush-fracture surface closure behavior during production; and

performing a simulation to forecast production efficiency.

16. The method of claim 11 , wherein the wellbore operation is a hydraulic fracturing operation using the elastic fluid and proppant; and wherein performing the hydraulic fracturing operation with the elastic fluid comprises;

mixing the proppant with the treatment of the elastic fluid; and

pumping the treatment of the elastic fluid mixed with the proppant according to one or more of a pressure with the pump system, a stimulation time with the pump system, a density of the proppant, and a diameter of the proppant from the determined operational parameters.

17. The method of claim 11 , further comprising:

obtaining, with the programmable control device, field data of the elastic fluid by collecting friction data at different rates and flow path restrictions and assessing the performance of the wellbore operation from the collected friction data; and

updating, with the programmable control device, the fluid parameters of the elastic fluid based on the obtained field data by improving the determination of the friction behavior of the elastic fluid with the collected friction data at the different flow rates and the flow path restrictions.

18. A method implemented with a wellbore system having a programmable control device and a pump system to perform a wellbore operation in a wellbore in a formation, the method comprising:

obtaining, with the programmable control device, wellbore parameters characterizing the wellbore operation in the wellbore, the wellbore operation requiring use of a target fluid having at least one target parameter of a transport performance, a suspension performance, a characteristic density, a characteristic viscosity, and a friction performance;

obtaining, with the programmable control device, fluid parameters characterizing an elastic fluid for use as the target fluid in the wellbore operation in the wellbore to achieve the at least one target parameter by:

(i) the fluid parameters are defined by regions of elastic behavior for the elastic fluid relating shear rate relative to viscosity of the elastic fluid, the regions of elastic behavior including a viscous region defined by the Power Law and including an elastic region defined by storage modulus (G′) relative to loss modulus (G″), and

(ii) the fluid parameters define, according to the regions of elastic behavior, friction behavior of the elastic fluid relating fiction gradient relative to flow rate of the elastic fluid, the fluid parameters of the elastic fluid being obtained from: (a) experimental data obtained of suspension performance of the elastic fluid; (b) the experimental data used in a 3D Model suspension test run up to a maximum concentration that (i) combines the experimental data with elasticity and viscosity parameters of the elastic fluid, and (ii) calibrates a particle transport model for the elastic fluid with numerical simulations for particle settling based on coupled Computational Fluid Dynamics (CFD) and Discrete Element Methods (DEMs); and (c) a particle-carrying capacity quantified for transport performance of the elastic fluid based on the particle transport model for the elastic fluid;

determining, with the programmable control device, operational parameters for using the elastic fluid as the target fluid in the wellbore operation in the wellbore to achieve the at least one target parameter by modeling the wellbore operation using the elastic fluid based on the wellbore parameters and the fluid parameters;

preparing a treatment of the elastic fluid having the fluid parameters by adding an elastic fluid agent to a base fluid; and

performing, through an interface of the programmable control device with the pump system, the wellbore operation by pumping the treatment of the elastic fluid in the wellbore with the pump system according to the determined operational parameters to reach the at least one target parameter.

19. The method of claim 18 , wherein the particle-carrying capacity of the elastic fluid is quantified with respect to density of the elastic fluid by performing numeric analysis.

20. The method of claim 18 , wherein the particle-carrying capacity of the elastic fluid is quantified with respect to various types and concentrations of particles by performing numeric analysis.

21. The method of claim 18 , wherein the friction behavior of the elastic fluid relating the fiction gradient relative to the flow rate of the elastic fluid is at least one of:

determined in two different friction segments, including a first of the friction segments for the viscous region defined by the Power Law, and a second of the friction segments for the elastic region defined by the storage modulus (G′) relative to the loss modulus (G″); and

determined by: friction loop testing of the elastic fluid performed in a plurality of pipe sizes at a plurality of different ones of the flow rates; and a plurality of the friction gradient of the elastic fluid estimated at the different flow rates for the plurality of pipe sizes.

22. The method of claim 18 , wherein the wellbore operation is a hydraulic fracturing operation using the elastic fluid and proppant; and wherein modeling the hydraulic fracturing operation using the elastic fluid based on the wellbore parameters and the fluid parameters comprises one or more of:

optimizing the operational parameters based on a selection of the elastic fluid, a type of the proppant, a concentration of the proppant, and a pumping rate of the elastic fluid and the proppant according to a stimulation objective;

modelling based on one or more of: reservoir depth, pore pressure gradient, porosity, permeability, total organic carbon (TOC), water saturation, Young's modulus, Poisson's ratio, rock strength, cohesion, and sh-min gradient;

performing a simulation to predict hydraulic fracture propagation, fracture height growth, and natural fracture reactivation;

performing a simulation to model transport of the proppant within both main hydraulic fractures and a reactivated natural fracture network;

performing a simulation to assess embedment of the proppant and crush-fracture surface closure behavior during production; and

performing a simulation to forecast production efficiency.

23. The method of claim 18 , wherein the wellbore operation is a hydraulic fracturing operation using the elastic fluid and proppant; and

wherein performing the hydraulic fracturing operation with the elastic fluid comprises pumping the elastic fluid and the proppant according one or more of a pressure, a stimulation time, a density of the proppant, and a diameter of the proppant from the determined operational parameters.

24. The method of claim 18 , further comprising:

obtaining, with the programmable control device, field data of the elastic fluid by collecting friction data at different rates and flow path restrictions and assessing the performance of the wellbore operation from the collected friction data; and

updating, with the programmable control device, the fluid parameters of the elastic fluid based on the obtained field data by improving the determination of the friction behavior of the elastic fluid with the collected friction data at the different flow rates and the flow path restrictions.

25. A programmable storage device having program instructions stored thereon for causing a programmable control device to perform a method according to claim 1 .

Assignments (1)

Continuity (3)

References Cited (49)