Casing wear estimation

Patent metadata

Field	Value
Publication number	US-9976416-B2
Application number	US-201314355436-A
Country	US
Kind code	B2
Filing date	Jun 25, 2013
Priority date	Jun 25, 2013
Publication date	May 22, 2018
Grant date	May 22, 2018

Abstract

Casing wear estimation. At least some of the illustrative embodiments are methods including: calculating a value indicative of static casing wear of the drilling operation, the static casing wear caused by interaction of a drill string against an inside diameter of a casing; calculating a value indicative of impact casing wear of the drilling operation, the impact casing wear caused by interaction of the drill string against the inside diameter of a casing; and combining the value indicative of static casing wear and the value indicative of impact casing wear to determine the value indicative of aggregate casing wear.

First claim

What is claimed is:

1. A method of determining casing wear during drilling operations, the method comprising:
receiving, by a computer system from one or more sensors disposed within a drill string, an indication of the drill string's interaction with an inside diameter of a casing during a drilling operation along a first section of a wellbore;
calculating a value indicative of static casing wear caused by interaction of the drill string against the inside diameter of the casing during the drilling operation, based on the received indication;
selecting at least one model from a plurality of models, each model based on a respective cross-sectional wear pattern;
calculating a value indicative of impact casing wear caused by interaction of the drill string against the inside diameter of the casing during the drilling operation, based on the selected model;
combining the value indicative of static casing wear and the value indicative of impact casing wear to determine a value indicative of aggregate casing wear for the first section of the wellbore;
adjusting one or more drilling parameters associated with the drilling operation, based on the value indicative of aggregate casing wear; and
performing the drilling operation along a second section of the wellbore according to the one or more adjusted drilling parameters.

2. The method of claim 1 , wherein selecting the at least one model comprises:
selecting a first model from the plurality of models for a first portion of the casing corresponding to the first section of the wellbore; and
selecting a second model from the plurality of models for a second portion of the casing corresponding to the second section of the wellbore, wherein the second model is distinct from the first model, and the second portion of the casing is at a different depth than the first portion of the casing.

3. The method of claim 2 , wherein calculating the value indicative of impact casing wear based on the selected model comprises:
calculating a first value based on the first model;
calculating a second value based on the second model; and
calculating the value indicative of impact casing wear based on the first and second values.

4. The method of claim 1 , wherein the at least one model is selected from the group consisting of: a model based on a parabolic cross-sectional wear pattern; a model based on an elliptical cross-sectional wear pattern; a model based on a sinusoidal cross-sectional wear pattern; and a model based on a pattern where a single wear peak is offset radially from a static wear peak.

5. The method of claim 1 , wherein the one or more sensors include vibration sensors for measuring vibration of the drill string during the drilling operation, and calculating the value indicative of impact casing wear comprises:
calculating the value indicative of impact casing wear based on the selected model and the vibration measured by the vibration sensors.

6. The method of claim 5 , wherein the value indicative of impact casing wear is at least one of: a value of an impact force of the drill string's interaction with a portion of the casing as a function of time; a non-zero value indicative of impact casing wear in locations along the drill string where vibration is measured by the vibration sensors; or a zero value indicative of impact casing wear in locations along the drill string where no vibration is measured by the vibration sensors.

7. The method of claim 1 , wherein the respective values indicative of static casing wear and impact casing wear are calculated during at least one of a planning stage of the drilling operation prior to the drilling of the wellbore or while the wellbore is drilled during the drilling operation.

8. A system comprising:
a processor;
a memory coupled to the processor;
the memory storing a program that, when executed by the processor, causes the processor to:
receive, from one or more sensors disposed within a drill string, an indication of the drill string's interaction with an inside diameter of a casing during a drilling operation along a first section of a wellbore;
calculate a value indicative of static casing wear caused by interaction of the drill string against an inside diameter of an interval of casing during the drilling operation, based on the received indication;
select at least one model from a plurality of models, each model based on a respective cross-sectional wear pattern;
calculate a value indicative of impact casing wear caused by interaction of the drill string against the inside diameter of the interval of casing during the drilling operation, based on the selected model;
combine the value indicative of static casing wear and the value indicative of impact casing wear to determine a value indicative of aggregate casing wear for the interval of casing along the first section of the wellbore;
adjust one or more drilling parameters associated with the drilling operation, based on the value indicative of aggregate casing wear; and
perform the drilling operation by using the drill string to drill a second section of the wellbore according to the one or more adjusted drilling parameters.

9. The system of claim 8 , wherein the program, when executed by the processor, further causes the processor to:
calculate a plurality of values indicative static casing wear, each value at a respective for the interval of casing;
calculate a plurality of values indicative impact casing wear, each value at a respective for the interval of casing; and
combine the values at respective for the interval of casing to generate a plurality of values indicative of aggregate casing wear, each value of aggregate casing wear at a respective for the interval of casing.

10. The system of claim 8 , wherein the program further causes the processor to:
select a first model from the plurality of models for use with respect to a first interval of casing corresponding to the first section of the wellbore; and
select a second model from the plurality of models for use with respect to a second interval of casing corresponding to the second section of the wellbore, wherein the second model is distinct from the first model, and the second interval of casing is at a different distance along the wellbore than the first interval of casing.

11. The system of claim 10 , wherein the program further causes the processor to:
calculate a first value based on the first model;
calculate a second value based on the second model; and
calculate the value indicative of impact casing wear based on a combination of the first and second values.

12. The system of claim 8 , wherein the at least one model is selected from the group consisting of: a model based on a parabolic cross-sectional wear pattern; a model based on an elliptical cross-sectional wear pattern; a model based on a sinusoidal cross-sectional wear pattern; and a model based on a pattern where a single wear peak is offset radially from a static wear peak.

13. A non-transitory computer-readable medium storing a program that, when executed by a processor, causes the processor to:
receive, from one or more sensors disposed within a drill string, an indication of the drill string's interaction with an inside diameter of a casing during a drilling operation along a first section of a wellbore;
calculate a value indicative of static casing wear caused by interaction of the drill string against an inside diameter of a casing during the drilling operation, based on the received indication;
select at least one model from a plurality of models, each model based on a respective cross-sectional wear pattern;
calculate a value indicative of impac

Assignees

• Landmark Graphics Corp

Inventors

• Samuel Robello
• Aniket

Classifications

• G01N29/04

  Analysing solids (using acoustic emission techniques G01N29/14) · CPC title

• E21B49/003 Primary

  by analysing drilling variables or conditions (E21B49/005 takes precedence; systems specially adapted for monitoring a plurality of drilling variables or conditions E21B44/00) · CPC title

• E21B44/00

  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 title

• E21B47/00 Primary

  Survey of boreholes or wells (monitoring pressure or flow of drilling fluid E21B21/08) · CPC title