Methods for operating wellbore drilling equipment based on wellbore conditions

• US 10,711,546 B2
• Filed: 05/12/2015
• Issued: 07/14/2020
• Est. Priority Date: 05/12/2014
• Status: Active Grant

• Current Assignee: National Oilwell Varco LP (NOV, Inc.)
• Original Assignee: National Oilwell Varco LP (NOV, Inc.)
• Inventors: Turner, Rebekah, Veeningen, Daniel M.
• Primary Examiner(s): Bomar, Shane
• Application Number:
  US15/312,411
• Publication Number:
  US 20170122047A1
• Time in Patent Office: 1,890 Days
• CPC Class Codes: E21B 19/16 Connecting or disconnecting pipe couplings or joints E21B19/20 takes precedence
• CPC Class Codes: E21B 21/082 Dual gradient systems, i.e. using two hydrostatic gradients or drilling fluid densities
• 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 47/06 Measuring temperature or pressure
• CPC Class Codes: E21B 47/12 Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling

Abstract

A method, comprising acquiring annular pressure data from a wellbore where the annular pressure data is acquired over a time interval and at least a portion of the annular pressure data is acquired during a pumps-off period. At least first and second values are identified from the annular pressure data and the variation between the first and second values are compared to a first threshold. Drilling equipment is operated based on the comparison with the first threshold.

Claims

1. A method, comprising:

acquiring annular pressure data from a wellbore, wherein the annular pressure data is acquired over a time interval and at least a portion of the annular pressure data is acquired during a pumps-off period;

identifying at least first and second values from the annular pressure data;

comparing the variation between first and second values to a first threshold, wherein the first threshold follows a trend over a plurality of different drill pipe connections of variations of annular pressure data, wherein the trend is a function of length of uncased wellbore; and

increasing at least one of drill string hoisting speed, and drill string hoisting acceleration based on the comparison with the first threshold.

2. The method of claim 1, wherein the annular pressure data comprise at least one of equivalent densities and normalized equivalent densities.

3. The method of claim 1, further comprising:

comparing the variation between the first and second values to a second threshold, wherein the second threshold follows a trend over the plurality of different drill pipe connections of variations of annular pressure data, wherein the trend is a function of length of uncased wellbore; and

decreasing at least one of drill string hoisting speed, and drill string hoisting acceleration based on the comparison with the second threshold.

4. The method of claim 1, wherein the at least first and second values are identified from the annular pressure data measured during the pumps-off period, wherein the first value is identified prior to making a drill pipe connection and the second value is identified while setting a drill string in slips or while picking up the drill string off slips.

5. A method, comprising:

acquiring annular pressure data from a wellbore, wherein the annular pressure data is acquired over a time interval and at least a portion of the annular pressure data is acquired during a pumps-off period;

computing equivalent densities based upon the acquired annular pressure data;

determining a first threshold by correlating the equivalent densities to drilling efficiency; and

determining a second threshold by correlating the equivalent densities to drilling efficiency, wherein the second threshold is different from the first threshold;

measuring annular pressure data within the wellbore;

identifying at least first and second values from the measured annular pressure data;

comparing the variation between first and second values to the first threshold and the second threshold; and

operating drilling equipment based on the comparison with the first threshold and the second threshold.

6. The method of claim 5, wherein the at least first and second values are identified from the annular pressure data measured during the pumps-off period, wherein the first value is identified prior to making a drill pipe connection and the second value is identified after making the drill pipe connection.

7. The method of claim 5, wherein a pumping rate is determined based on comparing the variation to the threshold, and wherein a drilling fluid circulation pump is operated at the determined pumping rate during a pump ramp-up or slow-down period subsequent a drill pipe connection.

8. The method of claim 5, wherein a pumping duration is determined based on comparing the variation to the threshold, and wherein a drilling fluid circulation pump is operated for the determined pumping duration during a pump ramp-up or slow-down period subsequent a drill pipe connection.

9. The method of claim 5, wherein operating drilling equipment based on the comparison with the first threshold comprises controlling at least one of circulation rate, weight on bit, drill string rotation speed, drill string hoisting speed, and drill string hoisting acceleration.

13. The method of claim 5 wherein operating drilling equipment based on the comparison with the first threshold and the second threshold includes controlling at least one of drill string hoisting speed, and drill string hoisting acceleration based on the comparison with the first threshold and the second threshold.

14. The method of claim 13 wherein the at least first and second values are identified from the annular pressure data measured during the pumps-off period, wherein the first value is identified prior to making a drill pipe connection and the second value is identified while setting a drill string in slips or while picking up the drill string off slips.

15. The method of claim 13 wherein controlling at least one of drill string hoisting speed, and drill string hoisting acceleration based on the comparison with the first threshold and the second threshold includes:

increasing at least one of drill string hoisting speed, and drill string hoisting acceleration based on the comparison with the first threshold; and

decreasing at least one of drill string hoisting speed, and drill string hoisting acceleration based on the comparison with the second threshold.

19. The method of claim 5 wherein the first threshold follows a trend as a function of time, wellbore length, or driller depth.

20. The method of claim 19 wherein the second threshold follows a trend as a function of time, wellbore length, or driller depth.

10. A method comprising:

determining an equivalent density of a drilling fluid at a plurality of locations within a wellbore;

correlating the equivalent densities to drilling efficiency so as to determine a first threshold;

correlating the equivalent densities to drilling efficiency so as to determine a second threshold different from the first threshold;

acquiring annular pressure data from a location within the wellbore, wherein the annular pressure data is acquired over a time interval and at least a portion of the annular pressure data is acquired during a pumps-off period;

identifying at least first and second values from the annular pressure data;

comparing the variation between first and second values to the first threshold and the second threshold; and

operating drilling equipment based on the comparison with the first threshold and the second threshold.

11. The method of claim 10, wherein the at least first and second values are identified from the annular pressure data measured during the pumps-off period, wherein the first value is identified prior to making a drill pipe connection and the second value is identified after making the drill pipe connection.

12. The method of claim 10, wherein operating the drilling equipment comprises controlling at least one of pump ramp-up, pump slow-down, circulation rate, weight on bit, drill string rotation speed, drill string hoisting speed, and drill string hoisting acceleration.

16. The method of claim 10 wherein operating drilling equipment based on the comparison with the first threshold and the second threshold includes controlling at least one of drill string hoisting speed, and drill string hoisting acceleration based on the comparison with the first threshold and the second threshold.

17. The method of claim 16 wherein the at least first and second values are identified from the annular pressure data measured during the pumps-off period, wherein the first value is identified prior to making a drill pipe connection and the second value is while setting a drill string in slips or while picking up the drill string off slips.

18. The method of claim 16 wherein controlling at least one of drill string hoisting speed, and drill string hoisting acceleration based on the comparison with the first threshold and the second threshold includes:

increasing at least one of drill string hoisting speed, and drill string hoisting acceleration based on the comparison with the first threshold; and

decreasing at least one of drill string hoisting speed, and drill string hoisting acceleration based on the comparison with the second threshold.