Granted Patent B2

US 12,590,521 · App. 17/289,147 · Granted Mar 31, 2026

Inventors: Timothy Holiman Hunter (Duncan, OK); Stanley V. Stephenson (Duncan, OK)

Assignee: Halliburton Energy Services, Inc.

E21B43/26E21B43/2607G05D7/0682E21B2200/20

Abstract

Claims (39)

1 . A method of fracturing comprising:

pumping a wellbore treatment fluid into a subterranean formation using wellbore servicing equipment comprising a plurality of pumps;

varying a plurality of operational parameters of the wellbore servicing equipment;

observing a response of the wellbore servicing equipment;

generating a model of the plurality of pumps based on the response;

changing a horsepower output of two or more of the plurality of pumps based at least in part on the model to form an updated plurality of operational parameters such that a rate of wellbore treatment does not change more than about 10%;

pumping the wellbore treatment fluid into the subterranean formation using the wellbore servicing equipment wherein the wellbore servicing equipment is operated at the updated plurality of operational parameters; and

updating the updated plurality of operational parameters of the wellbore servicing equipment based at least in part on the model, such that the plurality of pumps are operated such that mechanical vibrations are avoided wherein the model is utilized to predict oscillation frequencies in manifold and discharge lines and the operational parameter of the wellbore servicing equipment is changed to reduce the oscillation frequencies in manifold and discharge lines.

2 . The method of claim 1 wherein the step of varying the plurality of operational parameters comprises varying at least one of output pressure or flow rate of pumps.

3 . The method of claim 1 wherein the plurality of pumps are connected to a first side of a manifold and a second side of the manifold and wherein varying the plurality of operational parameters comprises increasing at least one of pressure or flow rate of at least one pump on the first side of the manifold while decreasing at least one of pressure or flow rate of at least one pump on the second side of the manifold.

4 . The method of claim 1 wherein the plurality of operational parameters comprise RPM, rate, pressure, density, or a combination thereof.

5 . The method of claim 1 wherein the wellbore servicing equipment comprises at least one of blenders, pumps, discharge lines, manifolds, and combinations thereof.

6 . The method of claim 1 wherein the response comprises a response to ambient temperature change, oil temperature change, transmission fluid temperature change, fluid density change, fluid rate change, fluid pressure change, or a combination thereof.

7 . The method of claim 1 wherein the step of observing the response comprises observing a temperature dependent response of pump horsepower.

8 . The method of claim 1 wherein the step of observing the response comprises observing a rate dependent response on cavitation.

9 . The method of claim 1 wherein the step of observing the response comprises observing a rate dependent response on beat frequencies.

10 . The method of claim 1 wherein the step of observing the response comprises observing a rate dependent response on mechanical resonances.

11 . The method of claim 1 further comprising recording the response in an operational database.

12 . The method of claim 1 wherein the model comprises at least one predictive correlation between at least one of ambient temperature and horsepower output of a pump, flow rate and pump cavitation, flow rate and beat frequencies, flow rate and mechanical resonance, flow rate and flow pulsation, or combinations thereof.

13 . The method of claim 1 wherein the step of changing at least one of the plurality of operational parameters based at least in part on the model comprises changing at least one operational parameter such that a fuel consumption of the wellbore servicing equipment is reduced while maintaining the rate of wellbore treatment.

14 . The method of claim 1 wherein the wellbore servicing equipment is fluidically coupled to a common manifold and a blender.

15 . The method in claim 1 wherein response is stored in an operational database operatively associated with the model, and wherein the model predicts flow behavior of the one or more of the plurality of pumps, and wherein flow behavior is utilized to change the horsepower output of the two or more of the plurality of pumps.

16 . The method of claim 1 wherein varying the plurality of operational parameters of the wellbore servicing equipment comprises varying a density of the wellbore treatment fluid by changing an amount of proppant in the wellbore treatment fluid.

17 . A method of fracturing comprising:

pumping a wellbore treatment fluid into a subterranean formation using wellbore servicing equipment comprising a plurality of pumps;

varying a plurality of operational parameters of the wellbore servicing equipment;

observing a response of the wellbore servicing equipment;

generating a model of the plurality of pumps based on the response;

changing a horsepower output of two or more of the plurality of pumps based at least in part on the model to form an updated plurality of operational parameters such that a rate of wellbore treatment does not change more than about 10%; and

pumping the wellbore treatment fluid into the subterranean formation using the wellbore servicing equipment wherein the wellbore servicing equipment is operated at the updated plurality of operational parameters,

wherein the model is utilized to predict the operational parameter where equipment damage, pressure spikes, or both occur, and the operational parameter of the wellbore servicing equipment is changed to reduce equipment damage, pressure spikes, or both.

18 . A method of fracturing comprising:

pumping a wellbore treatment fluid into a subterranean formation using wellbore servicing equipment comprising a plurality of pumps;

varying a plurality of operational parameters of the wellbore servicing equipment;

observing a response of the wellbore servicing equipment;

generating a model of the plurality of pumps based on the response;

changing a horsepower output of two or more of the plurality of pumps based at least in part on the model to form an updated plurality of operational parameters such that a rate of wellbore treatment does not change more than about 10%;

pumping the wellbore treatment fluid into the subterranean formation using the wellbore servicing equipment wherein the wellbore servicing equipment is operated at the updated plurality of operational parameters; and

determining available rate of a pump in the plurality of pumps using the model and updating a pump schedule based on the determined available rate of the pump and bringing one pump in the plurality of pumps offline and utilizing the model to determine one or more pumps in the plurality of pumps to redistribute rate to such that such that the rate of wellbore treatment does not change more than about 10%.

Assignments (1)

Continuity (1)

References Cited (18)