Fracturing operations controller

Patent metadata

Field	Value
Publication number	US-11913446-B2
Application number	US-201917291388-A
Country	US
Kind code	B2
Filing date	Nov 5, 2019
Priority date	Nov 5, 2018
Publication date	Feb 27, 2024
Grant date	Feb 27, 2024

Abstract

A system can include one or more processors; memory; a data interface that receives data; a control interface that transmits control signals for control of pumps of a hydraulic fracturing operation; and one or more components that can include one or more of a modeling component that predicts pressure in a well fluidly coupled to at least one of the pumps, a pumping rate adjustment component that generates a pumping rate control signal for transmission via the control interface, a capacity component that estimates a real-time pumping capacity for each individual pump, and a control component that, for a target pumping rate for the pumps during the hydraulic fracturing operation, generates at least one of engine throttle and transmission gear settings for each of the individual pumps using an estimated real-time pumping capacity for each individual pump where the settings are transmissible via the control interface.

First claim

What is claimed is:

1. A system ( 2800 ) comprising:
one or more processors ( 2810 );
memory ( 2820 ) accessible to at least one of the one or more processors;
a data interface ( 2830 ) that receives data acquired by one or more sensors operatively coupled to one or more pumps, wherein the one or more sensors comprise a pump discharge pressure transducer and a pumping rate sensor;
a control interface ( 2840 ) that transmits control signals to at least one of the one or more pumps;
a modeling component ( 2850 ), operatively coupled to at least one of the one or more processors, that predicts pressure in a well using a model, an intended pumping rate, and at least a portion of the data indicative of an actual pumping rate and a well head pressure estimate, wherein the well is fluidly coupled to at least one of the one or more pumps;
a pumping rate adjustment component ( 2860 ), operatively coupled to at least one of the one or more processors, that, in a predicted pressure mode, generates, using a predicted pressure of the modeling component and a pressure threshold, a pumping rate control signal for transmission via the control interface; and
a pressure change rate component, operatively coupled to at least one of the one or more processors, that generates a pressure change rate using a well head pressure estimate and historical pressure data and that outputs the pressure change rate to the modeling component, wherein the modeling component generates the predicted pressure using the pressure change rate.

2. The system of claim 1 wherein the at least a portion of the data indicative of an actual pumping rate comprises data acquired by the pumping rate sensor.

3. The system of claim 1 , comprising a well head pressure estimation component, operatively coupled to at least one of the one or more processors, that receives, via the data interface, data acquired by the pump discharge pressure transducer to generate the well head pressure estimate.

4. The system of claim 1 , comprising an interface that receives treating pressure versus pumping rate data, wherein the pumping rate adjustment component, in an alternative mode, generates the pumping rate control signal using the treating pressure versus pumping rate data without using the predicted pressure.

5. The system of claim 1 , comprising a model update component that receives one or more inputs to the modeling component, that receives the pumping rate control signal, that utilizes the one or more inputs to the modeling component and the pumping rate control signal to determine accuracy of the pumping rate control signal, and that updates the model based at least in part on the determined accuracy.

6. The system of claim 1 , wherein the modeling component comprises a pressure friction model that predicts a friction pressure that is a function of pumping rate and a fluid friction property.

7. The system of claim 6 , comprising a pressure friction model update component that receives pump down pressure data and that updates the pressure friction model using at least a portion of the pump down pressure data, wherein the pump down pressure data comprise pressure data from an operation that pumps down a perforation unit into a subterranean tubular.

8. The system of claim 7 , wherein the pressure friction model utilizes one or more instantaneous shut-in pressures (ISIPs) and one or more pressures prior to a shut-in for one or more stages of hydraulic fracturing to determine one or more friction pressures.

9. The system of claim 8 , comprising a component that utilizes the one or more friction pressures to adjust a friction pressure curve and that utilizes the adjusted friction pressure curve to estimate a friction pressure for a subsequent stage of hydraulic fracturing.

10. The system of claim 8 , comprising a component that utilizes the one or more friction pressures to adjust a friction pressure curve and that utilizes the adjusted friction pressure curve to estimate a bottom hole pressure.

11. The system of claim 10 , comprising a component that analyzes the estimated bottom hole pressure to determine one or more treatment abnormalities.

12. The system of claim 10 , comprising a component that analyzes the estimated bottom hole pressure to determine indicia of screenout.

13. The system of claim 12 , comprising a component that utilizes the indicia of screenout to generate a pumping rate control signal to generate the pumping rate control signal for transmission via the control interface to change a pumping rate.

14. The system of claim 1 , comprising a cluster component that generates estimates of fracture coverage that depend on one or more operational parameters.

15. The system of claim 14 , wherein the pumping rate control signal generated by the pumping rate adjustment component is implemented in a manner dependent on one or more of the estimates of fracture coverage.

16. The system of claim 14 , wherein the cluster component generates estimates of fracture coverage that depend on step down test data.

17. The system of claim 16 , wherein the cluster component analyzes pressure and flow rate to estimate at least one of perforation dominance and tortuosity dominance of a fracturing operation.

18. The system of claim 14 , wherein the estimates of fracture coverage comprise estimates for delivery of fluid via perforations of a stage of a multi-stage hydraulic fracturing operation.

19. A method ( 2882 ) comprising:
receiving data acquired by one or more sensors operatively coupled to one or more pumps, wherein the one or more sensors comprise a pump discharge pressure transducer and a pumping rate sensor ( 2883 );
predicting pressure in a well using a model, an intended pumping rate, and at least a portion of data indicative of an actual pumping rate and a well head pressure estimate, wherein the well is fluidly coupled to the one or more pumps ( 2884 );
generating, in a predicted pressure mode, a pumping rate control signal using the predicted pressure and a pressure threshold ( 2885 ) and utilizing a pressure friction model that predicts a friction pressure that is a function of pumping rate and a fluid friction property; and
transmitting the pumping rate control signal via a control interface to control operation of the at least one of the one or more pumps ( 2886 ).

20. The method of claim 19 , comprising operating in an alternative mode, wherein the generating generates the pumping rate control signal using treating pressure versus pumping rate data without using the predicted pressure.

21. The method of claim 19 , wherein the pressure friction model depends on pump down pressure data from an operation that pumps down a perforation unit into a subterranean tubular and/or wherein the pressure friction model depends on one or more instantaneous shut-in pressures (ISIPs) and one or more pressures prior to a shut-in for one or more stages of hydraulic fracturing.

22. The method of claim 19 , comprising utilizing a friction pressure curve to estimate a bottom hole pressure and, wherein the bottom hole pressure is indicative of screenout, generating an adjusted pumping rate control signal for reducing risk of screenout and transmitting the adjusted pumping rate control signal via the control interface to control operation of the at least one of the one or more pumps.

23. The method of claim 19 comprising generating estimates of fracture coverage that depend on one or more operational parameters, wherein the generatin

Assignees

• Schlumberger Technology Corp

Inventors

• Mu Nan
• Weng Xiaowei
• Lesko Timothy Michael
• Matthews James
• Kajita Marcos Suguru
• Mi Bao
• Bagulayan Amal
• Daube Francois
• Hobbs Brandon Travis
• Kuhn De Chizelle Yan P
• Menasria Samir
• Ho Kevin

Classifications

• F04B51/00

  Testing machines, pumps, or pumping installations · CPC title

• F04B2203/0602

  Vibration · CPC title

• F04B2203/0206

  Vibration · CPC title

• F04B2201/0802

  Vibration · CPC title

• F04B49/065 Primary

  and making use of computers · CPC title