DOWNHOLE TOOL MANAGEMENT SYSTEM

• US 20160342916A1
• Filed: 05/18/2016
• Published: 11/24/2016
• Est. Priority Date: 05/20/2015
• Status: Abandoned Application

• Current Assignee: Wellbore Integrity Solutions LLC
• Original Assignee: Schlumberger Technology Corporation (SLB)
• Inventors: Arceneaux, Jamie Lee, Deshpande, Ashish Prabhakar, Thomas, John Allen
• Application Number:
  US15/158,096
• Publication Number:
  US 20160342916A1
• Time in Patent Office: Days
• US Class Current: 1/1
• CPC Class Codes: E21B 10/26 Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers percussion drill bits with leading portion E21B10/40
• CPC Class Codes: E21B 17/00 Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
• CPC Class Codes: E21B 17/006 Accessories for drilling pipes, e.g. cleaners wear protectors E21B17/10; handling drilling pipes E21B19/00; thread protectors B65D59/00
• CPC Class Codes: E21B 47/13 by electromagnetic energy, e.g. radio frequency
• CPC Class Codes: G06Q 10/06313 Resource planning in a project environment
• CPC Class Codes: G06Q 10/067 Enterprise or organisation modelling

Abstract

A method for managing downhole tool assets includes acquiring downhole tool use data, acquiring downhole tool service data, and creating a downhole tool wear model based on the acquired downhole tool use and service data. The downhole tool wear model may be used to identify downhole tools for servicing. The downhole tool wear model may further be used to recommend specific downhole tools for an anticipated downhole tool job.

Claims

1. A method for managing downhole tool assets, comprising:

acquiring downhole tool use data;

acquiring downhole tool service data;

creating a downhole tool wear model based on the acquired downhole tool use and service data; and

using the downhole tool wear model, identifying one or more downhole tool assets for servicing or as recommended for an anticipated downhole job.

2. The method of claim 1, wherein creating the downhole wear model includes using historical downhole tool use and service data for a plurality of downhole tools and determining at least one wear rate.

3. The method of claim 2, the at least one wear rate including an average wear rate.

4. The method of claim 2, the at least one wear rate including a thread or tool joint deterioration rate.

5. The method of claim 1, the servicing including inspection, certification, or maintenance.

6. The method of claim 1, wherein identifying the one or more downhole tool assets as recommended for an anticipated downhole job includes recommending a plurality of downhole tools and identifying multiple geographical locations where the recommended downhole tools are located.

7. The method of claim 1, wherein the downhole tool use and service data consists of downhole use and service data of tubulars.

8. The method of claim 1, wherein acquiring downhole tool use data includes using wellsite equipment to automatically acquire at least an identifier of the downhole tool and make-up torque on the downhole tool.

9. The method of claim 8, wherein acquiring downhole tool use data further includes storing the make-up torque in an asset record corresponding to the downhole tool.

10. The method of claim 8, wherein the wellsite equipment includes an electromagnetic tag reader above a rig floor or on a make-up device.

11. The method of claim 10, wherein the electromagnetic tag reader is communicatively coupled to an automated power tong, automated iron roughneck, a pipe spinner, or a roughneck.

12. The method of claim 1, further comprising:

storing the downhole tool use data and the downhole service data.

13. The method of claim 1, further comprising:

providing a computer-accessible user interface for accessing a history of downhole tool use data and downhole tool service data.

14. The method of claim 1, wherein creating the downhole tool wear model based on the acquired downhole tool use and service data includes correlating downhole tool use data of a plurality of downhole tools with downhole tool service data of the plurality of downhole tools.

15. The method of claim 1, wherein creating the downhole tool wear model includes correlating wear or damage to at least three of the following:

well;

clamping force;

make-up torque;

formation type;

drilling fluid type;

rotating time;

pumping time;

weight-on-bit;

time in hole;

temperature;

pressure;

depth; and

location on drill string

16. A computing system comprising:

a processor;

computer-readable media including physical storage media storing computer-executable instructions that, when executed by the processor, cause the computing system to;

access downhole job data corresponding to an anticipated downhole job;

access current downhole tool data; and

generate a recommendation that one or more downhole tool assets be used for the anticipated downhole job, the recommendation being generated by applying a wear model based on historical wear or damage data to the current downhole tool data, and determining whether anticipated wear or damage of the one or more downhole tool assets is within an allowable threshold level.

17. The computing system of claim 16, wherein generating the recommendation includes automatically generating a request for shipping of a specific plurality of drill pipe downhole tool asserts from multiple geographic locations.

18. The computing system of claim 16, wherein generating the recommendation includes determining a location of a plurality of drill pipe downhole tool assets within a recommended drill string.

19. A computing system comprising:

a processor;

computer-readable media including physical storage media storing computer-executable instructions that, when executed by the processor, cause the computing system to;

access prior downhole tool data for one or more downhole tool assets used in a downhole job;

access downhole job data corresponding to the downhole job; and

automatically generate a recommendation that one or more downhole tool assets be serviced or inspected, the recommendation being generated by applying a downhole wear model based on historical wear or damage data and corresponding to the downhole job data to the prior downhole tool data, and determining whether wear or damage of the one or more downhole tool assets is expected to be within an allowable threshold level.

20. The computing system of claim 19, wherein automatically generating the recommendation includes automatically generating a request for inspection of servicing for the one or more downhole tool asserts.