Predicting temperature-cycling-induced downhole tool failure

Patent metadata

Field	Value
Publication number	US-10267138-B2
Application number	US-201415509060-A
Country	US
Kind code	B2
Filing date	Oct 8, 2014
Priority date	Oct 8, 2014
Publication date	Apr 23, 2019
Grant date	Apr 23, 2019

Abstract

One drilling method embodiment includes: obtaining a set of drilling parameters, possibly from a drilling plan; applying the set of drilling parameters to a physics-based model to obtain an estimated log of a downhole parameter such as temperature; and refining the estimated log using a data-driven model with a set of exogenous parameters. Temperature cycling and cumulative fatigue (or other measures of failure probability or remaining tool life) may be derived to predict tool failures, identify root causes of poor drilling performance, and determine corrective actions.

First claim

What is claimed is:

1. A drilling method that comprises:
obtaining a set of drilling parameters associated with a drilling plan for a well;
applying the set of drilling parameters to a physics-based model to obtain an estimated log of a downhole parameter, wherein the downhole parameter is a temperature of a tool, wherein the estimated log of the downhole parameter is an estimated temperature of the tool versus depth in the well or versus time in the drilling plan in the well, and wherein the physics-based model accepts the set of drilling parameters as inputs and generates as an output, for each instance of inputs, a depth or time and a value of the downhole parameter to include in the estimated log; and
employing a data-driven model to produce a predicted log of said downhole parameter based at least in part on said estimated log, wherein the predicted log of said downhole parameter is a predicted temperature of the tool versus depth in the well or versus time in the drilling plan in the well, and wherein the data-driven model accepts as inputs the estimated log and a log of an exogenous response that is not the temperature of the tool but that is correlated with the downhole parameter and generates as an output, for each instance of inputs, a depth or time and a value of the downhole parameter to include in the predicted log.

2. The method of claim 1 , further comprising: comparing the predicted log to measurements of the downhole parameter and responsively updating the data-driven model.

3. The method of claim 1 , wherein the method further comprises formulating a modified drilling plan based at least in part on the predicted log.

4. The method of claim 3 , wherein the modified drilling plan includes at least one modified limit on at least one drilling parameter in said set.

5. The method of claim 1 , wherein the exogenous response is selected from the group consisting of weight on bit, rotation rate, rate of penetration, and flow rate.

6. The method of claim 1 , wherein the set of drilling parameters comprises properties of a drilling fluid.

7. The method of claim 1 , further comprising: deriving a temperature cycling of the tool.

8. The method of claim 1 , further comprising: deriving a tool event forecast from the predicted log.

9. The method of claim 8 , wherein the tool event forecast comprises a cumulative stress fatigue exceeding a threshold.

10. The method of claim 8 , wherein the tool event forecast comprises a tool failure probability exceeding a threshold.

11. The method of claim 1 , wherein the predicted log is a function of position along a borehole trajectory, and said predicted log extends to a selected horizon distance beyond a current drilling tool position.

12. The method of claim 1 , wherein the predicted log is a function of time, and wherein said predicted log extends to a selected horizon time beyond a current time.

13. The method of claim 1 , wherein the data-driven model is an autoregressive forecasting model.

14. The method of claim 1 , wherein the data-driven model is a regression-based forecasting model.

15. A drilling system to extend a borehole in accordance with a drilling plan, the drilling system comprising:
a drilling string comprising a downhole tool; and
a processing unit that derives a temperature cycling prediction for the downhole tool by applying a physics-based model to a set of parameters associated with the drilling plan to obtain an estimated log of a downhole temperature of the downhole tool, and operates on the estimated log using a data-driven model to produce the temperature cycling prediction;
wherein the estimated log of the downhole temperature is an estimated downhole temperature of the downhole tool versus depth in a well or versus time in the drilling plan in the borehole, and wherein the physics-based model accepts the set of parameters associated with the drilling plan as inputs and generates as an output, for each instance of inputs, a depth or time and a value of the downhole temperature of the downhole tool to include in the estimated log; and
wherein the predicted log of said downhole parameter is a predicted temperature of the downhole tool versus depth in the borehole or versus time in the drilling plan in the borehole, and wherein the data-driven model accepts as inputs the estimated log and a log of an exogenous response that is not the downhole temperature of the downhole tool but that is correlated with the downhole temperature of the downhole tool and generates as an output, for each instance of inputs, a depth or time and a value of the downhole temperature of the downhole tool to include in the predicted log.

16. The system of claim 15 , wherein the data-driven model further operates on the set of parameters associated with the drilling plan.

17. The system of claim 15 , wherein based at least in part on a temperature cycling prediction for the downhole tool, the processing unit recommends servicing or replacement of the downhole tool.

18. The system of claim 15 , wherein based at least in part on a temperature cycling prediction for the downhole tool, the processing unit recommends limiting or modifying at least one parameter associated with the drilling plan.

Assignees

• Landmark Graphics Corp

Inventors

• Samuel Robello
• Aniket
• Dursun Serkan

Classifications

• E21B44/02 Primary

  Automatic control of the tool feed ({E21B44/005,} E21B44/10 take precedence) · CPC title

• E21B47/18

  through the well fluid {, e.g. mud pressure pulse telemetry} · CPC title

• E21B21/08

  Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure (valve arrangements therefor E21B21/10) · CPC title

• E21B49/00

  Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells · CPC title

• E21B21/00 Primary

  Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor (freeing objects stuck in boreholes by flushing E21B31/03) · CPC title