Methods to monitor system sensor and actuator health and performance

• US 20080183415A1
• Filed: 01/31/2007
• Published: 07/31/2008
• Est. Priority Date: 01/31/2007
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Dykstra, Jason D.
• Granted Patent: US 7,574,325 B2
• Time in Patent Office: Days
• US Class Current: 702/113
• CPC Class Codes: E21B 41/00 Equipment or details not covered by groups E21B15/00 - E21B40/00
• 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 47/00 Survey of boreholes or wells monitoring pressure or flow of drilling fluid E21B21/08

Abstract

A method for assessing health and performance of a system. In one example, the system comprises subsystems (preferably physically coupled subsystems), at least some of which are characterizable by transmitted signals. Some of these signals are transformed into a comparable form and compared, so as to identify signals that are outside of operating bounds.

Claims

1. A method of monitoring an oilfield equipment system, comprising the steps of:

identifying a physical coupling among three or more oilfield equipment subsystems;

monitoring a plurality of signals, each signal being associated with one of the three or more oilfield equipment subsystems;

transforming one or more of the oilfield equipment subsystem signals into units associated with the type of physical coupling among the three or more oilfield equipment subsystems;

comparing at least some of the signals; and

indicating at least one oilfield equipment subsystem'"'"'s signal that does not agree with at least two other oilfield equipment subsystems'"'"' signals.

2. The method of claim 1, wherein the type of physical coupling is selected from the group consisting of:

hydrostatic pressure, flow rate, and mass transfer.

3. The method of claim 1, further comprising the step of:

modifying a control algorithm based on an identified oilfield equipment subsystem signal.

4. The method of claim 1, further comprising the step of:

sending a signal to an operator identifying an oilfield equipment subsystem, where that subsystem'"'"'s signal does not agree with at least two other oilfield equipment subsystems'"'"' signals.

5. The method of claim 1, further comprising the step of:

when the step of comparing produces a result outside acceptable bounds, sending a signal to indicate the result is outside acceptable bounds.

6. The method of claim 5, wherein the acceptable bounds are selected from the group consisting of:

predetermined bounds, dynamical bounds, operationally dependent bounds, and bounds associated with dynamic constraints of a physical system.

7. The method of claim 1, wherein the units are selected from the group consisting of:

physical units, normalized expressions without physical units, and monotonic transformations of physical units.

8. The method of claim 1, further comprising the step of:

when the identified signal is an input to a control algorithm, replacing the identified signal'"'"'s input to the control algorithm with another signal without modifying the control algorithm.

9. A method of operating an oilfield equipment system, comprising the steps of:

controlling system operation using readings from multiple subsystems of the system;

checking the respective readings of said multiple subsystems against each other to determine whether any subsystems have readings which are physically inconsistent with each other; and

under at least some conditions, changing the controlling step to exclude the output of a respective subsystem which has been determined, in the checking step, to be showing inconsistent output.

10. The method of claim 9, further comprising the subsequent step of:

if the checking step ceases to detect inconsistencies, then, under at least some conditions, changing the controlling step again to include the output of a respective subsystem which had been excluded.

11. The method of claim 9, further comprising the step of:

when the step of checking produces a result outside acceptable bounds, sending a signal to indicate the result is outside acceptable bounds.

12. The method of claim 11, wherein the acceptable bounds are selected from the group consisting of:

predetermined bounds, dynamical bounds, operationally dependent bounds, and bounds associated with dynamic constraints of a physical system.

13. The method of claim 9, wherein if a first subsystem has been determined to be showing inconsistent output, replacing the first subsystem'"'"'s signal with a second subsystem'"'"'s signal as input to a control algorithm.

14. The method of claim 13, wherein the second subsystem'"'"'s signal is transformed into a form comparable to the first subsystem'"'"'s signal before being input into the control algorithm.

15. The method of claim 9, wherein at least one of the subsystems is selected from the group consisting of:

a sensor, an actuator, a mixer, and a pumping system.

16. A method for operating a system, comprising the steps of:

in a first procedure, monitoring a first sensor, and generating a first estimate of at least one parameter thereby;

in a second procedure, monitoring a second sensor, and generating a second estimate of said parameter thereby; and

comparing said first and second estimates to thereby selectively generate communications indicating undesired mismatch between said estimates.

17. The method of claim 16, wherein the first and second sensors are monitored in real time.

18. A method of controlling a complex system, comprising the steps of:

monitoring signals associated with a plurality of nodes in the system;

identifying a node from the plurality whose respective signal is outside an operation limit; and

switching from a first mode of operation to a second mode of operation in dependence on which node of the plurality has been identified as having a signal outside the operational limit.

19. The method of claim 18, wherein the step of switching modes comprises:

halting input into a control system from the identified node;

adding input into the control system from a different node; and

modifying a control algorithm to be controlled by the new input.

20. The method of claim 18, further comprising the step of:

when the step of checking produces a result outside acceptable bounds, sending a signal to indicate the result is outside acceptable bounds.

21. The method of claim 20, wherein the acceptable bounds are selected from the group consisting of:

predetermined bounds, dynamical bounds, operationally dependent bounds, and bounds associated with dynamic constraints of a physical system.

22. A method of monitoring an oilfield equipment system, comprising the steps of:

monitoring three or more signals at respective physical interfaces to at least one oilfield equipment subsystem, said signals being associated with physical states which are physically coupled but not identical;

transforming one or more of said signals into a set of units associated with the type of physical coupling between the three or more signals; and

indicating any oilfield equipment subsystem signal which is physically inconsistent with others of said signals.